Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
198-224
P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 9, 2025 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jessie Chmielowski: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells were found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitors, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Brennen Green or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, ConocoPhillips Well Integrity Field Supervisor RBDMS JSB 081425 Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@ conocophillips.com Reason: I am the author of this document Location: Date: 2025.08.11 16:34:01-08'00' Foxit PDF Editor Version: 13.1.6 Brennen Green ConocoPhillips Alaska Inc.Well Name API # PTD #Initial top of cementVol. of Portland Type I cement pumpedFinal top of cementCement top off date Corrosion inhibitorCorrosion inhibitor/ sealant datein gal in gal1C-17 50-029-22872-00-00 198-224 N/AN/A post SC Repair8" N/A 0.85 8/7/20251C-150 50-029-23496-00-00 213-120 N/AN/A Rig cemented to surface4" N/A 3 8/7/20251C-152 50-029-23548-00-00 215-114 50" 34.4 9" 7/31/2025 2.13 8/7/20251C-153 50-029-23549-00-00 215-116 N/AN/A Rig cemented to surface9" N/A 1.73 8/7/20251C-154 50-029-23559-00-00 215-166 70" 51.8 10" 7/31/2025 3.4 8/7/20251C-155 50-029-23561-00-00 215-180 64" 35.8 8" 7/31/2025 1.7 8/7/20251C-15650-029-23750-00-00 223-023 25" 12.00 10" 7/31/2025 5.1 8/7/20251C-157 50-029-23754-00-00 223-038 57" 30.28 9" 7/31/2025 2.2 8/7/20251C-15850-029-23761-00-00 223-056 3"N/A Rig cemented to surface10" 7/31/2025 4.25 8/7/20251C-501 50-029-23757-00-00 223-045 139" 11.40 8" 7/31/2025 3.8 8/7/20251H-107 50-029-23795-00-00 224-092 34" 14.80 10" 7/31/2025 5.25 8/7/20251H-11250-029-23787-01-00 224-032 47" 33.19 7" 7/31/2025 4.25 8/7/20251H-12050-029-23794-01-00 224-081 30" 13.70 8" 7/31/2025 4 8/7/20253H-3550-103-20805-00-00 219-064 45" 32.20 7" 8/1/2025 3.6 8/8/20253H-3650-103-20838-00-00 222-014 60" 44.20 8" 8/1/2025 3.4 8/8/20253H-3750-103-20822-00-00 219-194 35" 23.00 8" 8/1/2025 3.4 8/8/2025Date 08/09/251C, 1H, and 3H PadsKuparuk FieldReport of Sundry Operations (10-404)Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Originated: Delivered to:19-Jun-25Alaska Oil & Gas Conservation Commiss19Jun25-NR ! "# $$%$ !&$$'($)*%+ ($)*%,- .WELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED1C-158 50-029237-61-00-00 223-056 Kuparuk River WL TTiX-RST FINAL FIELD 7-Jun-251C-17 50-029228-72-00-00 198-224 Kuparuk River WL IPROF FINAL FIELD 8-Jun-253T-731 50-103209-05-00-00 224-156 Kuparuk River WL TTiX-HSD FINAL FIELD 10-Jun-253S-721 50-103209-11-00-00 225-025 Kuparuk River WL TTiX-SCMT FINAL FIELD 12-Jun-251A-22 50-029221-27-00-00 191-0003 Kuparuk River WL PPROF FINAL FIELD 17-Jun-25Transmittal Receipt//////////////////////////////// 0///////////////////////////////// + ! 1 Please return via courier or sign/scan and email a copy to Schlumberger. " 2"3 +45 %TRANSMITTAL DATETRANSMITTAL #1 67 8 " ! - +" 8 # !(3 . 8 ) "3 8 # !9 3 : 8" +8 6 8 8 " 8 # !;" " 3 - 3 " 3 ""+ 3 + < +3!% T40618T40619T40620T40621T406221C-1750-029228-72-00-00198-224Kuparuk RiverWLIPROFFINAL FIELD8-Jun-25Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.06.25 08:36:59 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: SC Repair & BH Weld Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10969 feet 10,291 feet true vertical 6757 feet feet Effective Depth measured feet 10,335 feet true vertical feet 6,163 feet Perforation depth Measured depth 10,690-10,852 feet True Vertical depth 6,495-6,647 feet Tubing (size, grade, measured and true vertical depth) 3 1/2 L-80 10,360 6,186 Packers and SSSV (type, measured and true vertical depth) SSSV: CAMCO TMAXX-5E 2,609 2,006 Packer:10,335 6,163 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 323-431 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. BAKER 80-40 SEAL ASSEMBLY Well Integrity Field Supervisor Brennen Green/Roger Mouser N1927@conocophillips.com measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 121 7 Gas-Mcf 6354 4 1/2 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 198-224 50-029-22872-00-00 P.O. Box 10036, Anchorage, Alaska 995103. Address: Conoco Phillips Alaska, Inc 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025638 / ADL0025649 KUPARUK RIVER/KUPARUK RIVER OIL KUPARUK RIV UNIT 1C-17 Conductor Surface 16 9 5/8 N/A Size MD measured TVD Production Liner 10,507 657 Casing Length 10,540 10,969 6163 Plugs Junk measured 659-7506 7597 4381 Burst Collapse N/A 80 7556 121 p k ft t Fra O s 198 6. A G L PG , d Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E =n1927@conocophillips.com Reason: I am the author of this document Location: Date: 2024.10.18 15:53:26-08'00' Foxit PDF Editor Version: 13.0.0 Brennen Green By Grace Christianson at 11:23 am, Oct 21, 2024 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 18, 2024 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Please find enclosed the 10-404 from ConocoPhillips Alaska Inc. for the Surface Casing repair and Braden Head weld on KRU 1C-17 (PTD 198-224). Feel free to contact me or my alternate, Roger Mouser, at 659-7506 if you have any questions. Sincerely, Well Integrity Field Supervisor N1927@conocophillips.com ConocoPhillips Alaska, Inc. Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@ conocophillips.com Reason: I am the author of this document Location: Date: 2024.10.18 15:53:01-08'00' Foxit PDF Editor Version: 13.0.0 Brennen Green Date Event Summary Executive Summary Repaired the Surface Casing leak @ ~23" below the OA valve with a 71" sleeve (77.5" total repaired area) and seal welded the Braden Head 10/17/24 (SC REPAIR) CEMENT THE CONDUCTOR (COMPLETE) (~13 gal of 15.8 lbs/gal Portland Type I / II cement) 10/16/24 (SC REPAIR) WELD CONDUCTOR (COMPLETE) (91.5" long x 0.500 wall x 16" diameter) 10/15/24 (SC REPAIR) AOGCC (ADAM EARL) WITNESSED SC REPAIR (COMPLETE), DENSO COAT & WRAP SC REPAIR SLEEVE AND WELDS (COMPLETE). 10/14/24 (SC REPAIR) REMOVE HEAT BLANKETS & PRO-HEAT LEADS AROUND BH (COMPLETE), MISTRAS MAG TEST BH WELD (PASSED), SCLD TO 1200 PSI W/N2 & LIFT GAS (PASSED). 10/13/24 (BH REPAIR) PRE-HEAT BH W/ MILLER PRO HEAT (COMPLETE). WELD BH (COMPLETE). CUT AND PREP CONDUCTOR FOR CONDUCTOR REPLACEMENT (COMPLETE). 10/12/24 (SC REPAIR) WELD ON SLEEVE (COMPLETE). MISTRAS INSPECTED SLEEVE WELDS (PASS). RIG UP MILLER PRO HEAT AND TEST (COMPLETE). Welders welded on Sleeve to collars (12.75" O.D. x 71"L x .500 wall x65). Total repaired area = 77.5" 10/11/24 (SC REPAIR) PRE-HEAT STARTING HEAD W/ MILLER PRO HEAT (COMPLETE). WELD "A" AND "B" COLLARS (COMPLETE). MISTRAS INSPECTED A & B COLLAR WELDS (PASS). Welders welded "A" band collars (upper and lower collars were stacked in the Fab Shop). Lower A Band collar: X-65 9.875" x 0.500 wall x 6" L. Upper A Band collar X-659.875" x 0.500 wall x 3" L. Welders welded "B" band collars (upper and lower collars were stacked in the Fab Shop). Lower B Band collar: X-65 9.875" x 0.500 wall x 8" L. Lower B Band collar X-65 9.875 x .500 wall x 4"L. 10/10/24 (SC REPAIR) PURGE OA (COMPLETE) 10/09/24 (SC REPAIR) RIG UP MILLER PRO HEAT (COMPLETE) 09/01/24 (SC REPAIR) IN PROGRESS - OA FLUID LEVEL @ 5'-5" BELOW WELD AREA (1" INFLOW OVER NIGHT), PURGED OA TO 50 PSI MULTIPLE TIMES WITH N2. 09/25/24 (SC REPAIR) IN PROGRESS- AOGCC (KAM ST. JOHN) VIEWED SURFACE DAMAGE, DRILL & TAP/PLUG KNOWN LEAK POINT, PT SURFACE CASING FOR OTHER LEAK POINTS, *** NEXT STEP EVACUATE FLUID TO 3' BELOW WELDING AREA*** 09/23/24 (SC REPAIR) IN PROGRESS- RECEIVED EMAIL FROM M.E. SUFFICIENT MATERIAL REMAINING TO CUT AND REMOVE CONDUCTOR. CUT TWO LARGE INSPECTION WINDOW , REMOVED CEMENT AND VERIFIED GOOD CASING WITHIN EXCAVATION AREA. ASRC CUT AND REMOVED 7' 3" OF CONDUCTOR. REMOVED CEMENT. PREPARED SC & BRADENHEAD AREA WITH WIRE WHEEL, FOR NDE PRIOR TO REPAIR. 09/22/24 (SC REPAIR) IN PROGRESS- ASRC CIVIL FINSHED CLEANUP OF EXCAVATION INSIDE CELLAR BOX. MISTRAS PERFORMED SECONDARY NDE TESTING FOR M.E. 09/21/24 (SC REPAIR) IN PROGRESS- ASRC CIVIL CREW EXCAVATING AND INSTALLING 9' DEEP 6'x6" CELLAR. REACHED 9' of 9' TD. 09/15/24 (SC REPAIR) IN PROGRESS- CUT INSPECTION WINDOWS, MISTRAS NDE TESTING COMPLETE. 09/08/24 (AC EVAL) DDT-T (PASS) DDT-IA (PASS) PURGE OA W/N2 (COMPLETE) 11/21/23 SET 2.75'' CA2 PLUG 10291' RKB, PERFORM PASSING MITT.. COMPLETE 11/20/23 ABLE TO OPERATE SSSV @ 2609' RKB (MIN 5500PSI ON C/L), PULLED PW TOOLSTRING @ 10291' RKB, TAGGED BOTTOM @ 10714' RKB, OBTAIN BHP @10375' RKB, BRUSH & FLUSH 2.75''D-NIP @10290' RKB. JOB IN PROGRESS 07/30/23 (AC-EVAL) SCLD (COMPLETE) LEAK IDENTIFIED @ 24", OA-DDT (PASSED) Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 10,714.0 1C-17 11/20/2023 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Update note about SSSV, pulled SL toolstring fish, set plug, updated tag depth 1C-17 11/21/2023 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: Welded a SC Sleeve over the SC leak (77.5" total repaired area) 10/12/2024 bsgreen NOTE: View Schematic w/ Alaska Schematic9.0 8/13/2010 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 41.0 121.0 121.0 62.58 H-40 WELDED SURFACE 9 5/8 8.83 40.3 7,596.8 4,380.8 40.00 L-80 BTC PRODUCTION 7 6.28 33.4 10,540.0 6,354.3 26.00 L-80 ABM-BTC LINER 4 1/2 3.96 10,311.8 10,969.0 12.60 L-80 NSCT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 36.6 Set Depth 10,359.6 Set Depth 6,185.6 String Max No 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 36.6 36.6 0.00 HANGER 8.000 TUBING HANGER 3.500 2,609.2 2,006.1 61.94 SAFETY VLV 5.176 CAMCO TMAXX-5E SAFETY VALVE *** NOTE - Minimum of 5500 psi on CL to have SSSV fully open *** 2.812 3,852.5 2,561.7 62.01 GAS LIFT 5.390 CAMCO KBMG 2.920 10,243.1 6,078.1 24.19 GAS LIFT 5.390 CAMCO KBMG 2.920 10,291.4 6,122.4 22.89 NIPPLE 4.540 CAMCO D NIPPLE 2.750 10,333.8 6,161.7 21.75 LOCATOR 5.000 BAKER LOCATOR 3.000 10,335.1 6,162.8 21.72 SEAL ASSY 4.000 BAKER 80-40 SEAL ASSEMBLY 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 10,291.0 6,122.1 22.90 TUBING PLUG Set 2.75" CA-2 plug (OAL = 28") in D nipple 11/21/2023 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,852.5 2,561.7 62.01 1 GAS LIFT DMY BK-5 1 0.0 12/18/2006 0.000 10,243.1 6,078.1 24.19 2 GAS LIFT DMY BK 1 0.0 12/28/2006 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 10,311.8 6,141.3 22.34 PACKER 4.500 BAKER ZXP LINER TOP PACKER 3.958 10,332.3 6,160.2 21.79 XO THREAD 4.500 3.958 10,344.5 6,171.6 21.53 XO THREAD 4.500 3.958 10,902.9 6,694.3 20.24 LANDING COLLAR 4.500 BAKER LANDING COLLAR 3.958 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,690.0 10,720.0 6,495.0 6,523.1 C-4, C-3, 1C-17 12/25/1998 4.0 IPERF 2.5" HC BH, 180 PH 10,720.0 10,750.0 6,523.1 6,551.2 C-3, 1C-17 10/7/2011 6.0 IPERF 60 DEG PHASE GUNS w/ DP HMX CHARGES 10,842.0 10,852.0 6,637.3 6,646.7 C-1, 1C-17 10/7/2011 6.0 IPERF 60 DEG PHASE GUNS w/ DP HMX CHARGES 1C-17, 10/18/2024 8:39:32 AM Vertical schematic (actual) LINER; 10,311.8-10,969.0 FLOAT SHOE; 10,967.1- 10,969.0 FLOAT COLLAR; 10,935.1- 10,936.3 LANDING COLLAR; 10,902.9- 10,904.0 IPERF; 10,842.0-10,852.0 IPERF; 10,720.0-10,750.0 IPERF; 10,690.0-10,720.0 PRODUCTION; 33.4-10,540.0 FLOAT SHOE; 10,538.5- 10,540.0 FLOAT COLLAR; 10,455.4- 10,456.7 SEAL ASSY; 10,335.1 SBE; 10,333.1-10,344.5 LOCATOR; 10,333.8 HANGER; 10,325.6-10,332.3 PACKER; 10,311.8-10,325.6 TUBING PLUG; 10,291.0 NIPPLE; 10,291.4 GAS LIFT; 10,243.1 SURFACE; 40.3-7,596.8 FLOAT SHOE; 7,595.1-7,596.8 FLOAT COLLAR; 7,516.1- 7,517.5 GAS LIFT; 3,852.5 SAFETY VLV; 2,609.2 CEMENTER; 2,592.2-2,594.9 CONDUCTOR; 41.0-121.0 HANGER; 40.4-42.6 HANGER; 36.6 KUP INJ KB-Grd (ft) 45.30 RR Date 12/2/1998 Other Elev 1C-17 ... TD Act Btm (ftKB) 10,969.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292287200 Wellbore Status INJ Max Angle & MD Incl (°) 64.73 MD (ftKB) 2,967.29 WELLNAME WELLBORE1C-17 Annotation Last WO: End Date 12/24/2006 H2S (ppm) DateComment SSSV: TRDP 2024-1015_Surface_Casing_Repair_KRU_1C-17_ae Page 1 of 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 10-16-2024 P. I. Supervisor FROM: Adam Earl SUBJECT: Surface Casing Repair Petroleum Inspector KRU 1C-17 CPAI PTD 1982240; Sundry 323-431 10-15-2024: I traveled to KRU 1C-17 to witness a surface casing repair. Brennen Green was the CPAI rep. on location. The welds of the sleeve looked good extending from approximately 8.5 feet below pad level to the Braiden head. I would describe this repair as one of the nicest I’ve witnessed. Attachments: Photos (3) 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.11.20 11:53:13 -09'00' 2024-1015_Surface_Casing_Repair_KRU_1C-17_ae Page 2 of 3 Surface Casing Repair – KRU 1C-17 (PTD 1982240) Photos by AOGCC Inspector A. Earl 10/15/2024 2024-1015_Surface_Casing_Repair_KRU_1C-17_ae Page 3 of 3 2024-0925_Surface_Csg_Corrision_KRU_1C-17_ksj Page 1 of 5 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 09/25/2024 P. I. Supervisor FROM: Kam StJohn SUBJECT: Surface Casing Corrosion Petroleum Inspector KRU 1C-17 ConocoPhillips Alaska, Inc. PTD 1982240; Sundry 323-431 09/25/2024: I arrived at KRU 1C-17 and met with Roger Mouser (CPAI DHD representative). Discussed the approved Sundry and procedure for addressing the surface casing damage. We inspected the corrosion damage to the surface casing. The Cellar box is 9 feet deep and the hole in casing is 23 inches below outer annulus valve. CPAI will drill the valve to tap and install a plug. CPAI crew will continue forward with corrosion damage repair per the approved Sundry. In addition to my photos, Roger Mouser sent some additional pictures to show where repair sleeves will be placed. Attachments: Photos (7) 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.11.07 11:29:03 -09'00' 2024-0925_Surface_Csg_Corrision_KRU_1C-17_ksj Page 2 of 5 Surface Casing Corrosion – KRU 1C-17 (PTD 1982240) Photos by AOGCC Inspector K. StJohn except as noted 9/25/2024 2024-0925_Surface_Csg_Corrision_KRU_1C-17_ksj Page 3 of 5 Photo courtesy of CPAI Photo courtesy of CPAI 2024-0925_Surface_Csg_Corrision_KRU_1C-17_ksj Page 4 of 5 Photo courtesy of CPAI Photo courtesy of CPAI 2024-0925_Surface_Csg_Corrision_KRU_1C-17_ksj Page 5 of 5 Photo courtesy of CPAI 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: SC REPAIR 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A 1C-17 Yes No 9. Property Designation (Lease Number): 10. Field: Kuparuk R Kuparuk River Oil N/A 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10,969' 6,757' 10.903' Casing Collapse Conductor Surface Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name:Roger Mouser / Brennen Green Roger Mouser Contact Email: N1927@conocophillips.com Contact Phone: (907) 659-7506 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY ConocoPhillips Alaska, Inc AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025638 198-224 P.O. Box 100360, Anchorage, Alaska 99510 50-0292-2872-00-00 7,597' Length Size Proposed Pools: L-80 TVD Burst 10,360' 6,694' 16" 9.625" 80' 7,557' 10,540' 121' 4,381' 121' 12/14/2023 10,969'657' 3.5" 6,163' Baker ZXP LINER TOP, Baker 80-40 Seal Assembly. SSSV: CAMCO TMAXXX-5E Perforation Depth MD (ft): Packers MD-10,312' TVD 6,141, TVD. MD 10,335',TVD 6,163' SSSV MD 2,609', TVD 2,006' 3,5853', 10,243' 10,507' 4.5" 2,562'. 6.078' 6,354'7" Digitally signed by Roger Mouser DN: O=Conocophillips, CN=Roger Mouser, E=N1927@conocophilllips.com Reason: I am the author of this document Location: Date: 2023.07.31 10:29:25-08'00' Foxit PDF Editor Version: 12.1.2 Roger Mouser By Grace Christianson at 10:41 am, Jul 31, 2023 323-431 X SFD X Photo document repair SFD 50-029-22872-00-00 SFD 9/19/2023VTL 10/4/2023 10-404 DSR-7/31/23 KRU *&:JLC 10/4/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.10.04 13:24:09 -08'00'10/04/23 RBDMS JSB 100523 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 1C-17 (PTD#198-224) Suspected Surface Casing Leak Date:Wednesday, July 26, 2023 8:38:22 AM Attachments:1C-17 90-day TIO.pdf 1C-17.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Monday, July 24, 2023 10:22 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 1C-17 (PTD#198-224) Suspected Surface Casing Leak Chris— KRU WAG injection well 1C-17 (PTD#198-224) was observed by Operations as having a sudden fall off of the OA pressure. The well was shut-in immediately. DHD will conduct diagnostic testing of the well, and we will submit the appropriate paperwork for a path forward once that is identified. Attached is a well schematic and 90-day TIO plot. Please let me know if you have any questions or disagree with the plan. Thanks, Travis Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 41.0 Set Depth (ftKB) 121.0 Set Depth (TVD) … 121.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.835 Top (ftKB) 40.3 Set Depth (ftKB) 7,596.8 Set Depth (TVD) … 4,380.8 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.276 Top (ftKB) 33.4 Set Depth (ftKB) 10,540.0 Set Depth (TVD) … 6,354.3 Wt/Len (l… 26.00 Grade L-80 Top Thread ABM-BTC Casing Description LINER OD (in) 4 1/2 ID (in) 3.958 Top (ftKB) 10,311.8 Set Depth (ftKB) 10,969.0 Set Depth (TVD) … Wt/Len (l… 12.60 Grade L-80 Top Thread NSCT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 10,311.8 6,141.3 22.34 PACKER BAKER ZXP LINER TOP PACKER 3.958 10,325.6 6,154.0 21.97 HANGER BAKER HMC LINER HANGER 3.958 10,333.1 6,161.0 21.77 SBE BAKER SEAL BORE EXTENSION 4.000 Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.992 Top (ftKB) 36.6 Set Depth (ft… 10,359.6 Set Depth (TVD) (… 6,185.6 Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 36.6 36.6 0.00 HANGER TUBING HANGER 3.500 2,609.2 2,006.1 61.94 SAFETY VLV CAMCO TMAXX-5E SAFETY VALVE 2.812 10,291.4 6,122.4 22.89 NIPPLE CAMCO D NIPPLE 2.750 10,333.8 6,161.7 21.75 LOCATOR BAKER LOCATOR 3.000 10,335.1 6,162.8 21.72 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 3.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Zone Date Shot Dens (shots/ft )Type Com 10,690.0 10,720.0 6,495.0 6,523.1 C-4, C-3, 1C-17 12/25/1998 4.0 IPERF 2.5" HC BH, 180 PH 10,720.0 10,750.0 6,523.1 6,551.2 C-3, 1C-17 10/7/2011 6.0 IPERF 60 DEG PHASE GUNS w/ DP HMX CHARGES 10,842.0 10,852.0 6,637.3 6,646.7 C-1, 1C-17 10/7/2011 6.0 IPERF 60 DEG PHASE GUNS w/ DP HMX CHARGES Mandrel Inserts St ati on N o/ Top (ftKB) Top (TVD) (ftKB) Make Model OD (in)Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,852.5 2,561.7 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 12/18/2006 2 10,243.1 6,078.1 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 12/28/2006 Notes: General & Safety End Date Annotation 8/13/2010 NOTE: View Schematic w/ Alaska Schematic9.0 Comment SSSV: TRDP 1C-17, 3/25/2018 9:50:40 AM Vertical schematic (actual) LINER; 10,311.8-10,969.0 IPERF; 10,842.0-10,852.0 IPERF; 10,720.0-10,750.0 IPERF; 10,690.0-10,720.0 PRODUCTION; 33.4-10,540.0 SEAL ASSY; 10,335.1 LOCATOR; 10,333.8 NIPPLE; 10,291.4 GAS LIFT; 10,243.1 SURFACE; 40.3-7,596.8 GAS LIFT; 3,852.5 SAFETY VLV; 2,609.2 CONDUCTOR; 41.0-121.0 HANGER; 36.6 Last Tag Annotation Last Tag: RKB Depth (ftKB) 10,809.0 End Date 3/24/2018 Last Mod By jhansen8 Last Rev Reason Annotation Rev Reason: TAG End Date 3/25/2018 Last Mod By jhansen8 KUP INJ KB-Grd (ft) 45.30 Rig Release Date 12/2/1998 Annotation Last WO: End Date 12/24/2006 1C-17 H2S (ppm) Date ... TD Act Btm (ftKB) 10,969.0 Well Attributes Wellbore API/UWI 500292287200 Field Name KUPARUK RIVER UNIT Wellbore Status INJ Max Angle & MD Incl (°) 64.73 MD (ftKB) 2,967.29 Annular Communication Surveillance 25-Apr-2023Well Name:1C-17 Start Date:25-Apr-2023 24-Jul-2023Days:90 End Date:24-Jul-2023 50 60 70 80 90 100 110 120 130 140 150 0 500 1000 1500 2000 2500 3000 3500 4000 25-Apr-2328-Apr-231-May-234-May-237-May-2310-May-2313-May-2316-May-2319-May-2322-May-2325-May-2328-May-2331-May-233-Jun-236-Jun-239-Jun-2312-Jun-2315-Jun-2318-Jun-2321-Jun-2324-Jun-2327-Jun-2330-Jun-233-Jul-236-Jul-239-Jul-2312-Jul-2315-Jul-2318-Jul-2321-Jul-2324-Jul-23Temperature (degF)Pressure (PSI)Pressure Summary WHP IAP OAP WHT 0 1000 2000 3000 4000 5000 6000 7000 8000 25-Apr-2328-Apr-231-May-234-May-237-May-2310-May-2313-May-2316-May-2319-May-2322-May-2325-May-2328-May-2331-May-233-Jun-236-Jun-239-Jun-2312-Jun-2315-Jun-2318-Jun-2321-Jun-2324-Jun-2327-Jun-2330-Jun-233-Jul-236-Jul-239-Jul-2312-Jul-2315-Jul-2318-Jul-2321-Jul-23Injection Rate (BPD or MSCFD)Injection Rate Summary DGI MGI PWI SWI BLPD MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, June 14, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Matt Herrera P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1C-17 KUPARUK RIV UNIT 1C-17 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/14/2022 1C-17 50-029-22872-00-00 198-224-0 W SPT 6163 1982240 1541 2484 2486 2484 2479 554 631 631 630 4YRTST P Matt Herrera 5/17/2022 MIT-IA Performed to 1900 PSI Per Operations 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1C-17 Inspection Date: Tubing OA Packer Depth 1320 1900 1880 1875IA 45 Min 60 Min Rel Insp Num: Insp Num:mitMFH220518152330 BBL Pumped:0.7 BBL Returned:0.6 Tuesday, June 14, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.14 14:06:45 -08'00' Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Thursday, August 15, 2019 4:21 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 1C-17 (PTD 198-224) Update and return of well to normal operating status Attachments: 1C-17 90 day TIO trend 15.19.pdf, MIT KRU 1C-17 diagnostic MITIA 07-16-19.xlsx Chris, Kuparuk WAG injector 1C-17 (PTD 198-224) was reported last month for suspect IAxOA pressure convergence. Subsequent reporting the well passed an MITIA and pack off tests and substantial differential was created between the IA and OA pressures. During the following 30 day monitor period no pressure convergence or annular communication was observed. The well is being returned to 'normal' status. A 90 day TIO trend and 10-426 for the diagnostic MITIA are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist, CPF1 & 2 ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAM CawraPhWps Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophil1ips.com> Sent: Monday, July 15, 2019 1:53 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; Well Integrity Compliance Specialist CPF1 & 2 Subject: 1C-17 SPTD# 198-2241 Report of IAxOA convergence Attachments: 1C-17 90 Day TIO plot.PNG; 1C-17.pdf Chris- Kuparuk Injector 1C-17 (PTD #198-224) has shown a sudden IAxOA convergence. CPAI intends to leave the well on injection and conduct a series of initial diagnostics to investigate the suspected IAxOA communication. After the diagnostics have been completed, the IA and OA will be monitored for 30 days to verify integrity between the IA and OA and any attempted repairs will be relayed to the AOGCC. The proper paperwork for repair or continued injection will be submitted. Please let me know if you disagree with the plan. Attached are copies of the 90 day TIO plot and well bore schematic. Dusty Freeborn/Jan Byrne Wells Integrity Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM ca« Fhaaps MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,May 16,2018 TO: Regg Supervisor ' elf 5'. 1 l SUBJECT: Mechanical Integrity Tests P.I. \ CONOCOPHILLIPS ALASKA,INC. 1C-17 FROM: Austin McLeod KUPARUK RIV UNIT 1C-17 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry.1 NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1C-17 API Well Number 50-029-22872-00-00 Inspector Name: Austin McLeod Permit Number: 198-224-0 Inspection Date: 5/12/2018 Insp Num: mitSAM180513194125 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 1982240 'f Type Test sPT Test psi 1541 - T IA 820 820 1800 _j 1780 ' 1780 ' Well 1C-17 T e In' W';TVD 6163 PTD L- BBL Pumped: T 1.1 BBL Returned: I 1.1 OA 1 524 657' 654 • 651 Interval 4YRTST P/F P vi Notes: MIT-IA ' SCOW JUN U 4?0t Wednesday,May 16,2018 Page 1 of 1 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /¢?-- ~ ¢ File Number of Well History File PAGES TO DELETE RESCAN Color items - Pages: Grayscale, halftr~n~..~ nictures, oraohs, charts- Pages:! Poor Quality Original'- Pages: Complete n Other- Pages: DIGITAL DATA n Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Scanned by.Mildred TO RE-SCAN Daretha Nathan Lowell Notes: Re-Scanned by: Bevedy Mildred Daretha owell Date: ,..~/ TATE OF ALASKA • ALASKA OIL AN CONSERVATION COMMISSION IIK ECEIVED REPORT OF SUNDRY WELL OPERATIONS OCT 6 71.iI 1. Operations Performed: Abandon r Repair w ell '"-' Plug Fbrforations r Stimulate r Other r Alter Casing f PuII Tubing r Perforate New Pool r Waiver ] i _r bete p r� s ENS. Commission r Shutdow n r Perforate 67 Re -en er Suspended el l. r nct or t 'e 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Nurnber: ConocoPhillips Alaska, Inc. Development r Exploratory r .198 - 224 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic (`" Service 50- 029 - 22872 -00 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25638 " 1 C - 9. Field /Pool(s): . Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 10969 feet Plugs (measured) None true vertical 6756 feet Junk (measured) None Effective Depth measured 10903 feet Packer (measured) 10312 true vertical 6694 feet (true vertucal) 6141 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121 SURFACE 7556 9.625 7597 4380 PRODUCTION 10507 7 10540 6354 LINER 657 4.5 10969 6756 Perforation depth: Measured depth: 10690' 10750', 10842' 10852' True Vertical Depth: 6496- 6551', 6637' -6647' DE 0 7 Ol Tubing (size, grade, MD, and TVD) 3.5, L -80, 10360 MD, 6186 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER ZXP LINER TOP PACKER @ 10312 MD and 6141 TVD SSSV - CAMCO TMAXX - 5E SSSV @ 2609 MD and 2006 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 2592 Subsequent to operation 2677 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service P` Stratigraphic r 15. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX . GSTOR r WINJ I — WAG ;• GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact John Peirce 265 -6471 Printed Name John Peirce Title Wells Engineer Signature i l i z (N Phone: 265 -6471 Date le/25 / 1 s /.1� Form 10 -404 Revised 10/ 1 D�IIS OCT 2 6 2011 �6 •2G Submit Original Only ��-�6% 1C -17 Well Work Summary DATE SUMMARY 8/12/11 GAUGED TBG TO 2.77" TO D NIPPLE @ 101' RKB. TAGGED @ 10673' SLM WITH nx 2.125" DRIFT. BOTTOM OF PROPOSED PERFS: 10852'. READY FOR CTU. 9/22/11 PERFORMED FCO USING DIESEL GEL SWEEPS TO 10866.9' CTMD. ENCOUNTERED HARD TAG AT 10865.4 UNABLE TO PASS THROUGH. POOH CHANGED NOZZLES. RIH AND MADE IT TO 10,866.9' CTMD. UNABLE TO MAKE IT ANY DEEPER. POOH AND TURNED OVER TO DSO. JOB COMPLETE. 10/7/11 PERFORATE C -SAND INTERVALS: 10,852- 10,842, 10,750- 10,720. 2.0" 6SPF 60DEG PHASE GUNS WITH DP HMX CHARGES. TAG DEPTH OF 10,887' RKB . •UP 1 110 1C -17 OCtoCOP}1fl 1p5 4 Well Attributes Max Angle & MD A1&s°�a k t Wellborn APUUWI Field Name Well Status Inc! ( °) MO (ftKB) Act Btm (ftKB) uF+rxmiu' a'" 500292287200 KUPARUK RIVER UNIT INJ 64 73 _2,967.29 109690 Comment I H2S (ppm) Date Annotation End Date KB (ft) Rig Release Dale w (cgnfl 1C.1( 1a SSSV TRDP Last WO' 12/24/2006 45.30 12/2/1998 "' S A Annotation Depth (ftKB) End Date Annotation Last Mod .. E d Date __ _. e9c:_. GA+aI Last Tag SLM ` 10,887 0 � 10/7/2011 I Rev Reason: ADD PERFS, TAG nlnam 10/8/2011 Casing Strings Casing Description String 0... String ID .. Top (ftKB) Set Depth (f_. Set Depth (ND) ... String Wt... String ... String Top Thrd HANGER,37 " = /•!: -- CONDUCTOR 16 15.062 41.0 121.0 121.0 62.58 H WELDED : ♦w -. Casing Description String 0... - String ID ... Top (8 Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd esc SURFACE 9 5/8 8.835 40.3 7,596.8 4,380.3 40.00 L-80 BTC --- _.� -..__ __. , Casing D Des ription String 0... String ID ... Top (kKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd _ PRODUCTION 7 6 276 33.4 10,540.0 6,354.3 26.00 L-80 ABM -BTC Description - -. -__ I _._- - - -- - -, Casing Description String 0... String ID .Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top p Thrd LINER 4 172 3 10,311.8 10,969 0 12.60 L -80 NSCT Liner Details Top ept k1r .ti'... i 'o- -. Nomi... ( T p (ftK _ (1NDD) 1K6) C) Item Desc ption _ Comment - -_ MOO Top Inc/ 10,311.8 6,141.3 22.34 PACKER BAKER ZX LINER TOP PACKER 3.958 _ 10 6,154. 21.97 HANGER BAKER HMC LINER HANGER 3 cONDUCTOR, 10,333.1 6,161.0 21.77 SBE BAKER SEAL BORE EXTENSION 4.000 Tubing Strings Tubing Descript String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (ND) ... String Wt... ■Str ng .. IStri g Top Thrd TUBING 31/2 2.992 36.6 10,3596 6,1857 930 I L-80 ABM -EUE Completion Details Top Depth (T1/D) Top Inc' Top (fIKB) B) r) Item Description Comment -. -. -. -.- ID (in) 'uf 36.6 36.6 0.00 HANGER TUBING HANGER 3.500 SAFETI'VLV.__ - .�--. - -- 2,6092 2,006.3 61.94 SAFETY VLV CAMCO TMAXX -SE SAFETY VALVE 2.812 10,291.4 6,122.6 22.89 NIPPLE - -- CAMCO D NIPPLE 2.750 10,333.8 6,161.7 21.75 LOCATOR BAKER LOCATOR 3.000 10,335.1 6,162 8 21.72 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 3.000 Perforations & Slots � � _ Shot Top (TVD) Btm (TVD) Dens GAS 385'2 _ ' �- - Top (kKB) Btm (ftKB) (ftKB) (811(13) Zone Date ( sh... ..1„)(p___ Comment 10,690 10,720 6 495.0 6,523.1 C-4, C -3, 1C-17 12/25/1998 4.0 IPERF 2.5" HC BH, 180 PH 1 10,720 10,750 6,523.1 6,551.2 C -3, 1C -17 10/7/2011 6.0 IPERF 60 DEG PHASE GUNS w/ DP HMX CHARGES { 10,842 10,852 6,637.3 6,646.7 C -1, 1C -17 10/7/2011 6.0 IPERF 60 DEG PHASE GUNS w/ DP HMX �.{ CHARGES Notes: General & Safety End Dale Annotation SU soass7 RFACE, ___ 8/13/2010 NOTE: View Schematic w/ Alaska Schematic9.0 GAS LIFT, __. * 10,243 I • NIPPLE, 10,291 - { - y LOCATOR. 10,334 1 \ SEAL ASSY. -_ _ . 10,335 111 i PRODUCTION„_ 33- 10,540 IPERF, '''''''-^:-'-C'. - -- _. _- -.- -- - ,ems. :, 10,690- 10.720 wa. V, �tlandret Details Top Depth TOp 10,720 - 10,750 (ND) Inc/ Port OD Valve Latch Size TRO Run --- Ste Top B (kKB) (°) Make Model ( Sery Type Type (in) (p5) Run Date Con... 1 3,852.5 2,561.7 62.01 CAMCO KBMG 1 GAS LIFT DMY 8K-5 0.000 0.0 12/18/2006 IPERF.- 1oa42 -tease � 2 10,243.1 6,078.1 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 12/28/2006 II ! I [ LINER, 10,312 - 10,969 TD, 10,969 MEMORANDUM TO: Jim Regg ~~ ~ ~Z~ ~~~ P.I. Supervisor j FROM: John Crisp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 15, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC ] C-17 KUPARUK RIV UNIT 1 C-17 Src: Inspector NON-CONFIDENTIAL Reviewed By:~` n P.I. Suprv J Comm Well Name: KUPARUK RIV UNIT 1C-17 Insp Num: mitJCr100614093449 Rel Insp Num: API Well Number: 50-029-22872-00-00 Permit Number: 198-224-0 Inspector Name: John Crisp Inspection Date: 5/21/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1c-i7~ TypeInj. N' TVD 6163 IA ~ 9zo zzzo 'i z19o zlso ~ P.T.D 19szzao TypeTest SPT Test psi lsao OA o 0 0 0 - - Interval 4YRTST p~F, P ., Tubing 1525 1540 1540 1540 Notes: I.6 bbls pumped for test. h -Ya _~ ~I?~~t..d 6 J4.JL -3 ~~U ~1. ~~~~~L s:a03~J Tuesday, June 15, 2010 Page 1 of ] . . Conoc6Phillips Alaska RECEIVED AUG 2 9 2007 Alaska Oil & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 23, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~w SEI' 06 2\\\\7 .\C\~ - d- -vLf . Dear Mr. Maunder: Enclosed please f!.nda spreadsheet with a list of wells ftom the Kuparuk field (KRU). Eac!1 of thesé wells was found to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped between August 19 & 21,2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. Æ4~~/ M.J.¿el~d ConocoPhillips Well Integrity Projects Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/21/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date .- ft bbls ft gal 1 0-28 204-237 18" N/A N/A N/A 10 8/19/2007 1 0-30 200-104 24" N/A N/A N/A 6.5 8/19/2007 10-34 200-143 14" N/A N/A N/A 4 8/19/2007 10-12 199-084 1" N/A N/A N/A 1.7 8/20/2007 10-14 199-089 2" N/A N/A N/A 3.4 8/20/2007 10-140 200-136 29'9" 3.4 12" 12/16/2006 14.5 8/20/2007 10-141 200-112 SF N/A N/A N/A 0.5 8/20/2007 '1C-11 199-.172 - SF NA NA NA :0.5 8/21/2007 1C-12 196-177 SF NA NA NA 0.5 8/21/2007 1C-15 198-229 SF NA NA NA 0.5 8/21/2007 1C-16 198-246 22" NA NA NA 8 8/21/2007 1C-17 198-224 17" NA NA NA 1.7 8/21/2007 1C-18 199-005 SF NA NA NA 0.5 8/21/2007 1 C-24 201-248 20" NA NA NA 11 8/21/2007 1C-26 199-051 3" NA NA NA 0.85 8/21/2007 1C-27 199-043 4" NA NA NA 1.7 8/21/2007 1 C-28 205-104 SF NA NA NA 0.5 8/21/2007 1C-117 201-121 26" NA NA NA 12.3 8/21/2007 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~e.rt z/:V/D7 DATE: Monday, January 29,2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IC-I? KlJPARUK RIV UNIT IC-I? FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv 31512-- Comm Well Name: KUPARUKRIV UNIT IC-17 Insp Num: mitCS070122I51005 Rei Insp Num NON-CONFIDENTIAL API Well Number 50-029-22872-00-00 Permit Number: 198-224-0 Inspector Name: Chuck Scheve Inspection Date: 1/2112007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 2550 2540 2540 860 860 860 1725 1725 1725 Well P.T. .. tnJ~.IT.ªL.m................ P/F Notes Pretest pressure observed and found stable. SCANNED FEB 0 7 2007 Monday, January 29,2007 Page I of I . STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION . REPORT OF SUNDRY WELL OPERA TIONi RECEIVED JAN 1 6 2007 aska Oil & Gas Cons. 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other AnclWtage Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. ShutdownO Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 198-224 1 306-396 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22872-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 41', Pad 61' 1 C-17 8. Property Designation: 10. Field/Pool(s): ADL 2563à, ALK 463 Kuparuk River Field 1 Kuparuk Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 10969' feet true vertical 6756' . feet Plugs (measured) Effective Depth measured 10468' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SURFACE 7556' 9-5/8" 7597' 4380' PRODUCTION 10500' 7" 1 0540' 6354' LINER 657' 4-1/2" 1 0969' 6757' Perforation depth: Measured depth: 10690'-10720' true vertical depth: 6495'-6523' SCANNED JAN 2 5 2007 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 10334' MD. Packers & SSSV (type & measured depth) Baker ZXP packer @ 10312' Cameo TMAXX-5E SSSV @ 2609' 12. Stimulation or cement squeeze summary: Intervals treated (measured) none Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casina Pressure Tubinn Pressure Prior to well operation SI -- Subsequent to operation 3000 . -- 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: OilO GasO WAG 0 GINJO WINJ0 ' WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Jill Long @ 265-1102 Printed Name Jill Long (n~ Title Wells Group Engineer / I /.., . Phone Date 0 I ISO 1 Signature C... l~ pJl 1/0 S -- 11 0 2.. Preoared bv Sharon AI/sun-Drake 263-4612 Ú Of1IG RBDMS 8Ft. Form 10-404 Revised 04/2004 'í 5 2007 Submit Original Only ( INAL Ai> /,¡.7>Þ7 /tf1Æ, . ConocoPhillips Alaska,lnc. SURFACE (0-7597. OD:9.625, Wt:40.00) 'RODUCTION (0-10540, OD:70oo, Wt:26.00) Gas Lift ,ndrel/Dummy Valve 1 (3852-3853, 00:5.390) Gas Lift ,ndrel/Dummy Valve 2 10243-10244, . OD:5.390) NIP 10291-10292, OD:5.ooo) LOCATOR 10334-10335, OD:5.ooo) LINER 10312-10969, OD:4.5OO, Wt:12.60) SEAL '10335-10336. OD:4.ooo) Perf 10690-10720) API: 500292287200 SSSVT e: TRPD Annular Fluid: DSUFW Reference Lo : Last Ta : 10468 Last Date: 12/17/2006 De 2609 10291 10334 10335 2006 6122 6162 6163 T e SSSV NIP LOCATOR SEAL . KRU 1C-17 Well T e: INJ Or; Com letion: 12/2/1998 Last W/O: 12/24/2006 Ref Lo Date: TO: 10969 ftKB Max Hole An Ie: 65 de 2967 An Ie TS: 20 de 10685 An Ie TO: 20 de 10969 Rev Reason: GL V C/O Last U date: 1/512007 CAMeo TMAXX-5E SSSV CAMeo '0' NIPPLE BAKER LOCATOR BAKER 80-40 SEAL ASSEMBLY ConocJPt,illips Time Log Summary We/Mew Web Reporting Well Name: 1 C-17 Job Type: RECOMPLETION 12/18/2006 14:00 18:00 4.00 MIRU MOVE MOB P Cont. Move Nordic rig #3 to 2B pad. Move camp on 1C-17. 18:00 18:30 0.50 MIRU MOVE MOB P Crew change at rig. 18:30 00:00 5.50 MIRU MOVE MOB P Resume move rig from 2B pad. 12/19/2006 00:00 05:00 5.00 MIRU MOVE MOB P Continue move 2T-208 to KOC 05:00 06:00 1.00 MIRU MOVE WOCC P WIO crew change KOC personnel. 06:00 08:00 2.00 MIRU MOVE MOB P Resume move KOC to 1C-17 08:00 09:00 1.00 MIRU MOVE PSIT P PJSM, spot rig over well 1C-17 09:00 10:30 1.50 COMPZr MOVE RURD P PJSM, RU, prepare for well work. 10:30 12:00 1.50 COMPZr RPCOtl. RURD P RU lubricator, pull BPV. 12:00 13:30 1.50 COMPZr RPCOtl. RURD P PJSM, MU circ lines to tree 1 annulus, test lines to 3000 psi. 13:30 20:00 6.50 COMPZr RPCOtl. RURD P Lay hard lines to kill tank while wait on arrival kill tank. 20:00 22:30 2.50 COMPZr RPCOtl. CIRC P Hold PJSM. Circulate 490 bbls of Seawater down tubing taking returns up IA. Get small amount of gas in beginning of circulation. Return wt of 8.5 on seawater. 22:30 00:00 1.50 COMPZ~ RPCOtl. NUND P Verify well is dead. Set BPV and start to ND tree 12/20/2006 00:00 02:00 2.00 COMPZ~ RPCOtl. NUND P ND Tree. Install blanking plug. 02:00 02:30 0.50 COM PZ~ RPCOtl. NUND P Inspect tree for re-use. All tree components in good condition, will re-use tree. 02:30 06:30 4.00 COMPZ~ RPCm NUND P PJSM, NU BOPE 1 all components. 06:30 08:00 1.50 COMPZ~ WELCì NUND P Change rams to 3 1/2. 08:00 13:00 5.00 COMPZ~ WELCì BOPE P PJSM, test BOPE to 250/3000, annular 250/2500 psi. All tests successful, no re-tests. Witness waived by Mr Jeff Jones AOGCC 13:00 15:00 2.00 COMPZr RPCOtl. PULD P PJSM, BOLDS, MU Idg jt, pull hgr to floor, remove same. Inspect, to re-dress seals 1 re-run. 12/20/2006 15:00 16:30 1.50 COMPZr RPCOI\ CIRC P Flow check, circ well clean, 6 bpm I 750 psi. No gain I loss. Tot circ ann vol X 2. Returns clean up at 131 bbls away. 16:30 17:00 0.50 COMPZr RPCOI\ PULD P PJSM, flow check, well static, commence POH laying dn tbg. in sgls. 17:00 23:30 6.50 COMPZr RPCOI\ PULD P Lay down first 160 jts and check for NORM. Send those 160 jts to Tuboscope for inspection and possible re-use. 23:30 00:00 0.50 COMPZr RPCOI\ PULD P Continue to POOH laying down singles. 180 jts out of hole at shift chanç¡e 12/21/2006 00:00 05:00 5.00 COMPZr RPCOI\ PULD P POOH laying down old 3-1/2" completion. Find some metal loss due to corrosion on pin ends of tubing, but no apparent holes located. Seals looked in good condition 05:00 06:30 1.50 COMPZI RPCOI\ OTHR P Cut drill line 06:30 12:00 5.50 0 0 COMPZr RPCOI\ OTHR P Load pipe shed with 3 1/2 tbg. Prepare for completion, strap, drift, clean threads. 12:00 14:30 2.50 0 0 COMPZr RPCOI\ PULD P Place tbg equip rig floor, make ready for tbç¡ run. 14:30 15:30 1.00 0 0 COM pzr RPCOI\ RCST P PJSM, MU seal assy, 0 nipple, GSM, RIH same. 15:30 21:30 6.00 0 7,800 COMPZr RPCOI\ RCST P Flow check, follow seal assy with 3 1/2, 9.3, L80, EUE tbg. 21:30 00:00 2.50 7,800 9,000 COMPZr RPCOI\ RCST P RU control line to SCSSSV. Test line to 5900 psi for 10 min. continue to RIH wI completion. Band control line every joint with Stainless Steel bands. 12/22/2006 00:00 02:30 2.50 COMPZr RPCOI\ RCST P RIH with 3-1/2" completion. Run all 2400' of control line. 02:30 05:30 3.00 COMPZr RPCOI\ RCST NP Call out for more control line and splice control line on jt 327 to surface. Pressure test splice to 6600 psi. 05:30 06:00 0.50 COMPZr RPCOI\ RCST P Flow Check, Resume RIH 3 1/2 tbg with control line. 06:00 08:00 2.00 COMPZr RPCOI\ HOSO P Sting in PBR with pump, confirmed with press increase to 500 psi. Stop pump I bleed, cont. dn to seat on locator. Space out, calculate for pups. Difficulty stabbing PBR, rotate, work torque dn to seal assy. 08:00 09:30 1.50 COMPZr RPCOI\ HOSO P MU pups, hgr, control line connection. Press to 5K and hold. Tag PBR, PU 1 ft for circ. 09:30 11:30 2.00 COMPZr RPCOI\ CIRC P Circ 272 bbls inhibited seawater to annulus, 4 bpm at 400 psi. Note clean returns. 11 :30 12:00 0.50 COMPZr RPCOI\ HOSO P Land tbg hgr I sting into PBR. 12:00 13:00 1.00 COMPZr RPCOI\ RURD P RU for tbg test. 15:00 16:30 1.50 P PJSM, test tbg 2500 psi 115 min. Bleed tbg to 1500 psi. Test IA to 2500 psi I 30 min. Bleed tbg to 0 psi. Note SOV shear at 500 psi. Circ through SOV, confirm open. All tests successful. No re-tests. 16:30 21:00 4.50 RPCOI\ NUND P PJSM, set BPV, prepare and ND BOPE. 21:00 22:00 1.00 RPCOI\ NUND P NU Tree and adapter flange 22:00 00:00 2.00 RPCOI\ NUND P Test Pack-ofts. LDS leaking. Back out and re-tor ue. Test to 5000 si 12/23/200600:00 02:00 2.00 RPCOI\ NUND P Pull BPV. Set Tree Test Valve and test tree to 250/5000 si. 02:00 05:00 3.00 RPCOI\ NUND P Pull tree test valve. Pump 90 bbls of diesel down IA for freeze protect then let u-tube with tubin . 05:00 06:00 1.00 RPCOI\ NUND P Drain lines. Set BPV. Release Rig. 06:00 12:00 6.00 MOVE DMOB P . . SARAH PALIN, GOVERNOR AlASKA OIL AND GAS CONSERVATION COM~nSSION 333 W. 7" A VENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-75423 Jill Long Wells Group Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1 C-1 7 Sundry Number: 306-396 ~ ., 'd--J... 4- \'\ Dear Ms. Long: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this~ day of December, 2006 Enc!. . IJ7j /2./ t¡jþ RECEIVED STATE OF ALASKA ko1\,,\ UEC 1 5 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION 4J,.. ... APPLICATION FOR SUNDRY APPRO V A~Skó ¡J¡ Gas Cons. Commission 20 MC 25.280 Anchorage 1. Type of Request: Abandon D Suspend D Operational Shutdown D Perforate D Waiver D Other D Alter casing D Repair well 0 Plug Perforations D Stimulate D Time Extension D Change approved program D Pull Tubing 0' Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development D Exploratory D 198-224 3. Address: Stratigraphic D Service 0' 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22872-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Yes D No 0 1C-17 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25638: ALK 463 RKB 41', Pad 61' Kuparuk River Field 1 Kuparuk Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10969' 6756' 10693' 6498' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16" 121' 121' SURFACE 7556' 9-5/8" 7597' 4380' PRODUCTION 1 0500' 7" 1 0540' 6354' LINER 657' 4-1/2" x 1 0969' 6757' 3-1/2" 1 0342' 6169' . Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10690'-10720' 6495'-6523' 3-1/2" L-80 10316' Packers and SSSV Type: Packers and SSSV MD (ft) Baker ZXP packer @ 10312' Camco DS nipple 512' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program D BOP Sketch D Exploratory D Development D Service 0' 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat December 18, 2006 Oil D Gas D Plugged D Abandoned D 17. Verbal Approval: M"~: WAG D GINJ D WINJ 0 WDSPL D Commission Representative: \~/t5-ofo 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill Long @ 265-1102 Printed Name Jill LonQ ( ~~()Y0 Title: Wells Group Engineer Signature (~2I Phone 265-1102 Date IL J /5/ D IJJ )1 (, Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness '?J()( 0 - ,-=¥1 W Plug Integrity D BOP Test ~ Mechanical Integrity Test r;( Location Clearance D Other: ~~\. 'fv(, t", ""'--'-.) ~-',-- ~O ~ *"7 40 \..-\ '"'BDMS BF' 1 9 2006 Subsequent Form Required: '!"(" ". ..., . ì ( Date: /P- ~ 0 ,,06 ~ APPROVED BY Approved by: OMMISSIONER THE COMMISSION Form 10-403 Revised 06/2006 '0~ I (0/, _. Submit in DUPlicate,£. IJá 17.. It .::x.. o NA,L ~ ~ . . ConocóP'hillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 15, 2006 RECEIVED DEC 1 b 2006 Alaska Oil & Gas Cons. Commission Anchorage Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk We1l1C-17 (PTD# 198-224). Injection well 1C-17 was drilled and completed in 'the Kuparuk C4 & C3 sand intervals in December 1998. The well injected continuously until July 2005 when it failed a mechanical ./ integrity inner annulus test (MITIA). A leak detection video log confirmed the presence of one hole at 8,106' MD and a subsequent caliper log showed the tubing tö be in poor condition. Due to the overall poor condition of the tubing and the expected long well life needed to provide injection support to the area, 1C-17 is a poor patch candidate and requires a well workover to return the well to long term service. ~ The purpose of the proposed workover will be to pull the existing tubing string and replace it with a new one. Attached is a proposed schematic along with a general workover procedure. If you have any questions or require any further information, please contact me at my office (265- 1102) or on my cell (240-6574). I apologize for the short notice of this sundry application but this RWO was originally planned to start in January 2007. However, due to recent complications with another RWO candidate, the start date for 1 C-17 may need to be moved to early next week. Sincerely, ~ ~DYff Wells Engineer CPAI Drilling and Wells . . Kuparuk 1C-17 General Workover Procedure Pre-Ria Work 1. Set IBP below seal assembly, pressure test the plug, and pull valve in GLM 2. Load well with seawater circulating through open GLM 3. Freeze protect 4. Set BPV 5. Prepare location for arrival of Workover Rig General Workover Procedure 1. MIRU Workover Rig 2. NO tree, MU blanking plug, and pressure test BOPE. The last SBHP measurement was 2,851 psi on November 16, 2006, at 10,690' MO (6,495' TVO). This pressure reading corresponds to a pressure of 2,856 psi at mid-perf depth. Prior to rig arrival, a plug will be set in the liner below the seal assembly and the well loaded with seawater. Because of this, kill weight fluid should not be needed; however, in the event that the plug fails, the estimated brine weight needed at mid-perf would be 8.44 ppg. By utilizing seawater (-8.60 ppg) the RYVO will be performed in a 54 psi overbalanced condition. (Assuming a 125 psi overbalance, the brine weight would need to be 8.81 ppg.) > The calculated maximum possible surface pressure assuming a gradient of 0.1 psi/ft is 2,205 psi. 3. Pull tubing and run new tubing/new completion. Prior to setting the new completion, circulate out seawater leaving corrosion inhibitor in the IA. 4. NO BOPE, NU tree, and test tree 5. Set BPV 6. ROMO workover rig Post-Ria Work: 1. Pull BPV 2. Set OV in mandrel 3. PulllBP 4. Tag fill 5. Return to injection . ConocJ>í,illips Well: 1C-17 Field: Kuparuk . API: 500292287200 PTD: 198-224 2006 RWO PROPOSED COMPLETION WELLHEAD Lift threads: 3%" 8rd EUE BPV: 3" FMC ISA Model: FMC Gen 4A CONDUCTOR 16",62.58 ppf, H-40, welded SURFACE CASING 9%",40 ppf, L-80, BTC PRODUCTION CASING 7", 26 ppf, L-80, BTC-MOD TUBING 3%", 9.3 ppf, L-80, ABM-EUE LINER 4%",12.6 ppf, L-80, NSCT PERFS C-4, C-3 10,690'-10,720'MD 6,495'-6,523' TVD 4 spf, 12/25/98 A B J B J c NEW COMPLETION A: SCSSV: 3%" with 2.813" X profile 2,000' TVD= ,2,596' MD B: Gas Lift Mandrels No. MD TVD 1 2,399 2,500 2 -10,229 6,065 TYPE 1" KBMG 1" KBMG C: Nipple: 3W' with 2.75" D profile Place at least 1 full joint above seal assembly D: Seal Assembly @ 10,317' MD Last Tag: 11/16/06 Tag Depth: 10,693' RKB Fill: 27' fill above btm perf TD: 10,690' RKB Last Updated: 15-Dec-06 Updated by: JWL RE: lC-17 RWO Sundry Documents . . Thanks for the help today 'rom. I'm sorry that I didn't get back to you before you Ieft the office but yes, we are planning to test the BOPs to 3000 psi so we should be okay. And the BOP configuration will be similar to that of the 1 D wells. If something changes I wiJl notify you. Have a great weekend! Jill W. Long ConocoPhillips Alaska, Inc. Office: (907) 265-1102 Cell: (907) 240-6574 -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Friday, December 15, 20064:25 PM To: Long, Jill W Subject: Re: 1C-17 RWO Sundry Documents Jill, I need to be going. I presume the minimum BOP test pressure will be 3000 psi. That should be· sufficient given the MASP that will-rêsult with 0.1 psi/ft gas gradient. If you have any pressure tests that are higher, the BOP should be tested to at least that pressure. Have the Company Man contact the Inspector with an opportunity to witness the BOP test. You have approval to proceed with the workover. Please be sure the IA is tested by the rig when the completion is run. The rig can contact Problem Wells at 659-7224 if they don't have the fonn. A copy ofthis message should be available on the rig. Tom Maunder, PE AOGCC Thomas Maunder wrote, On 12/15120063:56 PM: HI Jill, What BOP test pressure are you proposing? Is the stack arrangement similar to what was done on the 1D wells? Look forward to your reply. Tom Maunder, PE AOGCC Long, Jill W wrote, On 12/15120063:35 PM: «1C-17 Sundry COE 2006-12-15.xls» «1C-17 Sundry Letter.doc» «1C-17 Sundry Procedure.doc» «1 C-17 Proposed Schematic.xls» Tom- lof2 12/19/20068:20 AM RE: IC-I7 RWO Sundry Documents . . Attached is the Sundry Application Form 10-403 and additional supporting documents. Please review and give me a call with questions. Thanks- Jill W. Long ConocoPhillips Alaska, Inc. Office: (907) 265-1102 Cell: (907) 240-6574 20f2 12/19/20068:20 AM '-~,~ \' e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: FIELD 1 UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparukl KRU/1C-17 07115/05 Arend 1 Sauvageau AES 1( lq(OS ~1 .~~ ~t!';.V·" \~l.:· Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.u5 o F o F Well P.TD. Notes: Well P.TD. Notes: Well P.TD. Notes: Test Details: SCANNED NO\f {1 3 2005 TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT KRU 1C-17 07-15-05.xls .1.1 \L LL-' J.JV........TVJJ.U.1L\,,¡U..1........J........L..t.. .. ....:.. '\,.... '" ~ e e Subject: 1 C-17 (PTD 1982240) Failed o/(jTIA F)·om: NSKProblem Well Supv<nt617@C:onocophilliþs.com> Date: Mon,18Ju12005 15;11:52-0800 ..' . . . . 1'C!'.:r:h.omaS;:iÌlaunder <tòrri jilauikier@admm.statë:àk.(i¡¡>; Jat:i1¢s: R,egg <.ïìiJ1c. regg@aqmiiu.tate.akhþ:;· ~OIijleckenstein@8dmin;S!ate.ak.us· Tom & Jim, 1C-17 produced water injector failed a diagnostic MITIA on 7/15/05 as noted on the attached MITIA form. The diagnostic MITIA was scheduled because the DSO found the IA pressure at 2100 psi on 7/14/05. The IA had been bled from 2100 to 1300 psi on 7/13/05. The injection rate was recently increased on 7/3/05 from 800 to 6000 BWPD, so the IA pressurization was initially believed to be due to thermal expansion. It was expected that the MITIA would pass and verify integrity. The injection rate has been pinched back to lower the IA pressure. TII/O as of 7/18/05; 1700/1800/450 at an injection rate of 1900 BWPD. This well has no prior history of annular communication problems. MITIAs passed on 7/12/03 & 6/18/03. A 90 day plot of wellhead pressures is attached. The tbg packott passed testing on 7/15/05, so tlhe TxlA communication is either tlhe packer or tbg. A plug will be set in the tbg and diagnostic pressure tests will be conducted to identify the leak location. Approval to keep the well on injection until the tbg plug is set is requested. The tbg plug will be set within the next week. Once leak detection diagnostics have been completed, injection will remain SI until an AOGCC approved repair is completed or an administrative relief approved. Please let me know if you have any questions, Marie McConnell Problem Well Supervisor 659-7224 «MIT KRU 1C-17 07-15-05.xls» «1C-17 WHP trend 4-19-05 to 7-18-05.gif» I :L".1~~ - i';.. 11ft" 3uDO 2'!UU 24UO 2100 1300 1501.1 D -- ---- - \ 1200 SOD bOO 30G 19-APR-05 14:41 WEEK lS-JUL-OS 14 :"1 18-JUL-05 11:01:24 rrir _ AI fØd 44 . . FLOW TiJBING PRESSURE ??7?")?? NEXT WELL DRILLSITE IG 17 ...-".,..-"'.............-......." f"'"" KRU IC-I7 Content-Description: MIT KRU IC-17 07-!5-05.xls Content-Type: applicationlvnd.ms-exce! Content-Encoding: base64 WHP trend 4-19-05 to Content-Description: I C-!7 WHP trend 4-19-05 to Content-Type: image/gif Content-Encoding: base64 1 of! 7/19/2005 9:26 AM MEMORANDUM TO: Randy Ruedrich ~c~_! ~ Chair -.~ THRU: Jim Regg P.I. Supervisor FROM: John H. Spaulding Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 18, 2003 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska Inc. 10 190, 09, 14, 17,26 Kuparuk River Unit Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. I~.~'n~.l ~ I~.v.~. I~ I~"~''~ I~°°° I~°°° I~°°° I~°°° WeUI lC-190 ITypetestl P ITestpsil 958 I casinel 3000130001300013000 P.T.D.I 2030030 Notes: We,,I 1c-o9 I Type,,j.I ~ IT.V.D. I6205 ITubing I 2370 12368 I 2370 P.T.D.I ,1821850 ITypetestl P ITestpsil 1551 I Casingl 400 I 31001 3125 I 3100 I P/F IE I Notes: I WellI 1C-14 I Typelnj. I G I T.V.D. I~ I Tubingl ~,0, I~,~ I~,~ I~,~ I lntervall 4 P.T.D.I 1980170 TypetestI P I Testpsil 1565 I Casingl 50 I 3000 I 3000 I 3000 I P/F I P Notes: WellI lC-17 I Type Inj.I S I T.V.D. 16145 I Tubing I 2370 I 2370 I~ I~,~ I Interval 4 P.T.D.I 1982240 TypetestI P ITestpsil 1536 I Casingl 1000 I 31001 31001 3050 I P/F Notes: WellI lC-26 [Type Inj.I S I T.V.D. 16433 I Tubing I ==~ I==~ I==~ I==~ I lntervall4 P.T.D.I 1990510 Type testI P I Testpsil 1608 I Casingl 900 I 3000 I 3000 I 3000 I P/F Notes: ype INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed: Attachments: Number of Failures: Total Time during tests: cc: MIT report form 5/12/00 L.G. 2003-0618_M IT_KR U_ 1 C-26_js .xls 7~9/2003 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich Commissioner THRU' FROM: Jim Regg P.I. Supervisor DATE: July 12, 2003 John H, Spaulding Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests BPX 1C 17, 174 KRU Kuparuk River Field Packer Depth Pretest Initial 15 Min. 30 Min. WellI 16-17 ITvpelnj. I S I T.V.D. I~ I Tu¢,I 2344 12455 12465 12464 Ilntervall 4 P.T.D.I 1982240 TypetestI P ITestpsil 1536 I Casingl 1350 I 3125 I 3125 I 3125I P/F I P Notes: We,,I 10-,74 IType,nj.I S I T.V.D. 13727 IT.bingI 1420 14412 I~ I~* Ilnterval[ I 'P.T.D.I 2030270 ITypetestl P ITestpsil '932" Icasingl 1300I 2500I 2400I 2400 Notes: WellI I Type Inj. P.T.D. I I Type test Notes: WellI I Type Inj. P.T.D. I I Type test Notes: Well[ I Type Inj. P.T.D. I I Type test Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to CPA' s KRU 1 C pad to witness the MIT's on the above wells. Jared Brake was the CPA rep. today. The pretest pressures were observed and found to be stable. The standard annulus pressure tests were then performed with both wells meeting the AOGCC criteria for a successful MIT. M.I.T.'s performed: 2_ Number of Failures: O Total Time during tests: 2_ Attachments: C.C: MIT report form 5/12/00 L.G. 2003-0712_M IT_KRU_I C-174_.js.xls 7/18/2003 Annular Disposal during the second quarter of 2002: h(1) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-15 10176 100 0 10276 371 10446 21093 March April CD2-25, CD2-50 2002 2002 2P-420 9479 i00 0 9579 150 0 '"" ~"-'~, ~/~, April ~.~" ~vv~. ~: --,~' A~, Heavenly 2002 2P-415A 26238 100 0 26338 52 4943 31333 March April 2P-431, 2P-422A, 2P-427, 2002 2002 Heavenly, Grizzly, 2P-441 CD2-49 27474 100 0 27574 386 0 27960 April May 2002 CD2-46, CD2-22, CD2-50 2002 CD2-17 14962 100 0 15062 372 0 15434 May 2002 June 2002 CD2-48, CD2-46 1D-11 32102 100 0 32202 235 0 32437 May 2002 June 2002 1D-103 CD2-32 18536 100 0 18636 379 0 19015 June 2002 June 2002 CD2-19, CD2-41 112-18 4176 100 0 4276 379 0 4655 June 2002 June 2002 1C-104 Total Volumes into Annuli for which Disposal Authorization Expired during the second quarter 2002: Freeze Protect Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 1J-09 24202 100 0 330 24632 Open, Freeze Protected May 2001 May 2001 1J-10 1C-17 33139 100 0 160 33399 Open, Freeze Protected May 2001 June 2001 1C-133, 1C-121, 1C- 123, 1C-127 CD2-42 33507 100 0 385 33992 Open, Freeze Protected June 2001 October CD2-24, CD2-33, CD2' 2001 15 2P-417 30965 100 0 887 31952 Open, Freeze Protected October March 2P-422, Grizzly, 2P-451, 2001 2002 2P-441, 2P-448, 2P- 422A, 2P-420 1C-27 31766 100 0 153 32019 Open, Freeze Protected June 2001 July 2001 1C-127, lC-117, 1C- 111, 1C-123 Annular Dis ~osaI durin the second quarter 6 c2001: .2y /'¢%//5 / h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date / 1C-17 33139 100 0 33239 0 33239 May 01 Jun 01 1C-133, 1C-121, 1C-123, 1C-127 ::, 2N-318 2883 100 0 2983 13995 16978 Dec 00 Jun 01 2N-302, 2N-314, 1J-03 16904 100 0 17004 13120 30124 Mar 01 May 01 1J-09, 1J-14, 1J-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 1J-10 CD2-42 18034 100 0 18134 0 18134 May 01 Jun 01 CD2-24 , 1C-27 3533 100 0 3633 0 3633 Jun 01 Jun 01 1C-127 Total Volumes into Annuli for which Disposal Authorization Expired during the second quarter 2001: ' Total Voiume ~" Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume ,Status of Annulus -~ 1D-11 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 1D-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 1D-38, 1D-30 CD1-25 ' 33487 100 0 33587 Open, Freeze Protected June 2000 August CD1-06, CD1-40, CD1- / 2000 35, CD 1-32, CD 1-24, CD 1-22A, CD 1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD 1-41 only CD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down :" ,. CD1-34 only -' CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CD1-28, CD1- 33, CD1-NQ1 " STATE OF ALASKA " .... ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1393' FNL, 4714' FEL, Sec. 12, T11 N, R10E, UM 5. Type of Well: Development __ Exploratory _ Stratigraphic __ Service__X (asp's 561569, 5968838) 6. Datum elevation (DF or KB feet) RKB 102 feet 7. Unit or Property name Kuparuk Unit 8. Well number lC-17 At top of productive interval 23' FNL, 1830' FWL, Sec. 2, T11 N, R10E, UM At effective depth At total depth 5206' FNL, 3476' FEL, Sec. 35, T12N, R10E, UM (asp's 557469, 5975552) 9. Permit number / approval number 198-224 / 10. APl number 50-029-22872 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 10969 feet Plugs (measured) 6756 feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 9 cu Yds High Early 121' 121' SURFACE 7495' 9-5/8" 330 sx AS III LW, 670 sx Class G, 7597' 4381' PRODUCTION 10438' 7" 175 sx C~ass G 1 0540' 6354' LIN ER 657' 4-1/2" 112 sx C~ass G 1 0969' 6756' LINER Tubing (size, grade, and measured depth) ======================= :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: Packers & S S SV (~pe & m eas ured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) : : i : used and final pressure Treatment description including volumes .......................................................... 14. Prior to well operation Subsequent to operation Representative Da y Average Production or Iniection Data Gas-Mcf Water-Bbl Casing Pressure ~[ubing .Pre~,su(~. ii;...... ;iiiii......i..i.i.i .ii~ .ii_ i..i i. i_i ;.;~ _i ~.! i.i i.~ i.i i.;. ;.~ ~ ~ i:!iiii i~i~iii~ii~',~ii ili!i!i i! ii!iii iiiiii~iiiil 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ Title Production Engineering Supervisor Jeff A. Sper~r Questions? Carl Jeff Spencer 659-7226 Date //~,~2~_~¢J~ ,/ Prepared by Robert Ohristensen 659-7535 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 1C-17 -__ DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/11/011Commenced EOR Injection Roll #1: Start: Stop Roll #2: Start Stop MD 10969 TVD 06757 Completion Date: 12/2/98 Completed Status: 1WINJ Current: T Name Interval Sent Received T/C/D D 9106 1-4 SPERRY MPT/GR/EWR4/CNP/SLD OH 3/4/99 3/9/99 ~ DGR/CNP/SLD-MD FINAL 121-11969 OH 3/11/99 3/11/99 L...L DGR/CNP/SLD-TVD FINAL 121-6756 OH 3/11/99 3/11/99 ~4L DGR/EWR4-MD FINAL 121-11969 OH 3/11/99 3/11/99 L.~L DGR/EWR4-TVD FINAL 121-6756 OH 3/11/99 3/11/99 R SRVY RPT SPERRY 0-10969. OH 12/8/98 12/8/98 Thursday, January 18, 2001 Page 1 of 1 Annular Di'~ ~osal durin the second quarter o ~2001: h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date 1C-17 33139 100 0 33239 0 33239 May 01 Jun 01 1C-133, 1C-121, 1C-123, 1C-127 2N-318 2883 100 0 2983 13995 16978 Dec 00 Jun 01 2N-302, 2N-314, 1J-03 16904 100 0 17004 13120 30124 Mar01 May01 1J-09, 1J-14, 1J-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 IJ-10 CD2-42 18034 100 0 18134 0 18134 May 01 Jun 01 CD2-24 1C-27 3533 100 0 3633 0 3633 Jun 01 Jun 01 1C-127 Total Volumes into Annuli Cor which Disposal Authorization Expired during the second quarter 2001: Total Voiume Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume VOlume Volume Status of Annulus ID-II 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 1D-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 1D-38, 1D-30 CD1-25 33487 100 0 33587 Open, Freeze Protected June 2000 August CD1-06, CD1-40, CD1- 2000 35, CD1-32, CD1-24, CD1-22A, CD1-43 , CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD 1-41 only CD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down CD 1-34 only CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CD1-28, CD1- 33, CD1-NQ1 !oo -o/7 '_r>,~. o 4c3 ° IT1 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 31, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kupamk Area Annular Disposal, Second Quarter, 2001 - REVISED Dear Ms. Mahan: Please find attached the revised report with the volumes disposed into surface casing by production casing annuli during the second quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the second quarter of 2001. We have revised the amount for CD2-42 because the original manifest incorrectly reported the CD2-24 annulus used for the disposal. Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader PM/skad CC: Marry Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kupamk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 17,2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kupamk Area Annular Disposal, Second Quarter, 2001 Dear Ms. Mahan: Please find attached the report with the volumes disposed into surface casing by production casing annuli during the second quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the second quarter of 2001. Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader PM/skad RECEIVED JUL 1 ccl Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kupamk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Well Files Alaska 0il & Gas Cons. Commission Anchorage Annular Disposal durin the second quarter o :2001' h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date ~ 1C-17 33139 100 0 33239 0 33239 May01 Jun01 1c-133, 1c-121, 1c-123, 1c-127 2N-318 2883 100 0 2983 13995 16978 Dec 00 Jun 01 2N-302, 2N-314, 1J-03 16904 100 0 17004 13120 30124 Mar01 May01 1J-09, 1J-14, 1J-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 1J-10 CD2-42 16902 100 0 17002 0 17002 May 01 Jun 01 CD2-24 1C-27 3533 100 0 3633 0 3633 Jun 01 Jun 01 1C~127 Total Volumes into Annuli for which Disposal Authorization Expired during the second quarter 2001' Total Voiume Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus ID-II 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 1D-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 1D-38, 1D-30 CD1-25 33487 100 0 33587 Open, Freeze Protected June 2000 August CD1-06, CD1-40, CD1- 2000 35, CD1-32, CD1-24, CD1-22A, CD1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD1-41 only CD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down CD1-34 only ~' CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CD1-28, CD1- 33, CD1-NQ1 I. 0 STATE OF ALASKA f ,"'-7 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Other_X Change approved program _ Pull tubing _ Variance _ Perforate _ Annular Disposal 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 41', Pad 61' feet 3. Address Exploratory __ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__X Kuparuk Unit 4. Location of well at surface 8. Well number 1393' FNL, 4714' FEL, Sec. 12, T11N, R10E, UM (asp's561569, 5968838) lC-17 At top of productive interval 9. Permit number / approval number 23' FNL, 1830' FWL, Sec. 2, T11 N, R10E, UM 198-224 At effective depth 10. APl number 50-029-22872 At total depth 11. Field / Pool 5206' FNL, 3476' FEL, Sec. 35, T12N, R10E, UM (asp's 557469, 5975552) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 10969 feet Plugs (measured) true vertical 6756 feet Effective depth: measured 10903 feet Junk (measured) true vertical 6694 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 9 cu yds High Early 121' 121' SURFACE 7495' 9-5/8" 930 sx AS III LW, 670 sx Class G 7597' 4380' PRODUCTION 10438' 7" 175 sx Class G 10540' 6354' LINER 657' 4-1/2" 112 sx class G 10969' LINER Perforation depth: measured 10690'-10720'["~ J==" =~'" --r~CEIVED M/ y j. 5 2001 true vertical 6495'-6523' Alaska Oil & Gas Cons. Commission Tubing (size, grade, and measured depth 3-1/2", 9.3#, L-80 Tbg @ 10316' MD. Anchoc~e Packers & SSSV (type & measured depth) No packer CAMCO DS @ 512' MD. 13. Attachments Description summary of proposal__ Detailed operations program __ BOP sketch__ LOT test, surface cement details, casing detail sheets, schematic __X 14. Estimated date for commencing operation 15. Status of well classification as: May 21,2001 16. If proposal was verbally approved Oil__ Gas__ Suspended __ Name of approver Date approved Service Water Iniector 17. I hereby c.~rtify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mark Chambers @ 265-1319 · " /' Title: Drilling Engineering Supervisor Date Signed ,, .~/,/'L~j~ ,._.~' (/'L~~' f~_.~_..,~.... Prepared by Sharon AIlsup-Drake 26344.~12 Ja~_~s / rantham -- FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no. Plug integrity __ BOP Test __ Location clearance __ ~, I ~, ~ ~-~ Mechanical Integrity Test__ Subsequent form required 10- ~ ~ ~..~- ~~[, ~'G~'E} [~Y Commissioner Date Approved by order of the Commission , ~ r,~ Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE KRU 1C-17 CONDUCTOR (0-121, OD:16.000, Wt:62.58) NIP (512-513, 0D:4.470) TUBING (0-1O316, OD:3.500, ID:2.992) SURFACE (0-7597, OD:9.625, Wt:40.00) ~RODUCTION - (0-10540, OD:7.000, Wt:26.00) Gas Lift landrel/Dummy Valve 1 (10229-10230, OD:6.018) SL- 1C-17 APl: 500292287200 SSSV Type: NONE Annular Fluid: DSL/FW Reference Log:I Last Tag: Last Tag Date: Casing String - ALL Size Top 16.000 0 9.625 0 7.000 0 4.500 10312 Tubing String - TUBING Size Top 3.500 0 Perforations Summary Well Type: INJ I Orig Completion: 12/2/98 Last W/O: Ref Log Date: TD: 10969 ftKB Max Hole Angle: 65 deg @ 2967 Angle (~ TS: 120 deg ~ 10685 Angle @ TD: 120 deg (~ 10969 Rev Reason:EzNEW SCHEM BY Last Update: 1/19/99 Bottom TVD t Wt Grade Thread 121 121 I 62.58 H-40 WELDED 7597 4380 40.00 L-80 10540 6354 I 26.00 L-80 BTC-MOD 10969 I 10969 12.60 L-80 I NSCT Bottom TVD Wt GradeI Thread 10316 6145 9.30 L-80 BTC ABM-EUE Interval TVD Zone Statu~Feet SPFiDate I Type Comment c-4,c-3 30 412/25/9~ PERF 2.5 HCBH, 180PH 10690 - 10720 6495 - 6523 / / Gas Lift MandrelsNalves Stn MD TVD Man Man V Mfr VType V OD Latch Port TRO Date VIv Mfr { Type Run Commen 1 10229 6065 CAMCOI MMM CAMCO DMY 1.5 RK 0.000 0 12/3/98 Other (plugs, equip., etc.) - JEWELRY DepthI TVDI Type I Description ID 512{ 5091 NIP ICAMCO DS NIPPLE 2.812 10277 6109 NIP CAMCO D NIPPLE 2.750 10316 6145 SEAL BAKER GBH-22 2.992 Annulus Disposal Transmittal Form Designation of the well or wells to receive drilling wastes: 1C-17 The depth to the base of freshwater aquifers and permafrost, if present: No Aquifers / Base Permafrost = 1,511 TVD RKB !A stratigraphic description of the interval exposed to the From the 9-5/8" shoe to the Cement top all that is open open annulus and other information sufficient to support is shale or minor non-hydrocarbon bearing sands. a commission finding that the waste will be confined and will not come to the surface or contaminate freshwater. A list of all publicly recorded wells within one-quarter mile and all publicly recorded water wells within one mile of the well to receive drillina waste: See attached map indicating no wells within 1/4 mile and no water wells within one mile of 1C-17. Identify the types and maximum volume of waste to be disposed of and the estimated density of the waste slurry: Types of waste can be drilling mud, drilling cuttings, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well and any added water needed to facilitate pumping of drilling mud or drilling cuttings. Maximum vnh iml~ ~'n hP nlmmnPrl iq RS) nnn hhl~ An estimate of maximum anticipated pressure at the outer casing shoe during annular disposal operations and calculations showing how this value was determined: Maximum anticipated pressure at casing shoe during disposal operations is 1,842 psi. See attached: calculation page. Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation: See attached: cementing reports, LOT/FIT reports and casing reports. Details that show the inner and outer casing strings have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: See attached: casing summary sheet and calculation pages. Any additional data required by the Commission to confirm containment of drillinq wastes: Maximum Pressure @ The Shoe 1C-17 Surface Casing: Size Weight Grade Shoe Depth Burst (100%) Burst (85%) Assumptions: 9-5/8 4O# L-80 7,597' MD / 4,380' TVD 5,750 psi 4,887 psi Water on Backside of 9-5/8" (Worst Case) 1,500 psi Maximum Injection Surface Pressure Maximum Mud Weight Required to Drill 1C-Pad West Sak Wells = 9.8 ppg Maximum Fluid Density to Burst 9-5/8" Casing: 4,887 psi + 8.3 ppg (.052) (4,380') = 1,500 psi + MW (.052) (4,380') MW = 23.17 ppg V/'/~¢~(~ ~ Maximum Pressure on 9-5/8" Shoe: Max Pressure = 1,500 psi + 9.8 ppg (.052) (4,380') - 8.3 ppg (.052) (4,380') Max Pressure = 1,500 psi + 2,232 - 1,890 Max Pressure =1,842 psi v'" /<F~C~v~ ¢;lt t.~, Maximum Fluid Density to Collapse 7" Casin.q 1C-17 Casing: Size Weight Grade Shoe Depth Collapse (100%) Collapse (85%) Assumptions: 11 26# L-80 10,540' MD / 6,354' TVD 5,410 psi 4,598 psi 9-5/8" Casing Shoe @ 4,380' TVD Inside 7" Casing - Diesel from 2,400' TVD to Surface (6.7 ppg) Inside 7" Casing - Seawater from 4,380' TVD to 2,400' TVD (8.4 ppg) Maximum Fluid Density to Collapse 7" Casin.q: 4,598 psi + 6.7 ppg (.052) (2,400') + 8.4 ppg (.052) (4,380' - 2,400') = 1500 + MW (.052) (4,380) MW = 21.07 ppg~ Phillips Alaska, .Ine~. 330 350 0 40 28O 30O 50 60 7O 80 270 26O 1 O0 220 210 Phillips Alaska, Inc. Pad lC 17 slot #17 Kuparuk River Unit North Slope, Alaska HORIZONTAL PLANE CLEARANCE REPORT by Baker Hughes INTEQ Your ref : PMSS <0 - 10969') Our ref : svy5884 License : Date printed : 7-May-2001 Date created : 16-Nov-1998 Last revised : 2-Dec-1998 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is n70 19 31.453,w149 30 2.691 Slot Grid coordinates are N 5968837.883, E 561567.906 Slot local coordinates are 1395.00 S 563.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 2000 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath WS lC E1 B-LAT (V.1.C),,106,Pad lC GMS <0-9700'>,,3,Pad lC GMS <0-7753'>,,5,Pad lC GMS <0-10243'>,,6,Pad lC GMS <0-9784'>,,7,Pad lC Unknown Data,,WS1,Pad lC PMSS <O-8677'>,,13,Pad lC PMSS <0 - l1918'>,,16,Pad lC MSS <0-7000'>,,9GI,Pad lC PMSS <0-6529'>,,23 PB1,Pad lC PMSS <1840-13975>,,23A,Pad lC PMSS <0-10140'>,,25,Pad lC PMSS <0-14630'>,,26,Pad lC GMS <0-7780'>,,1,Pad lC PMSS <0-9390'>,,15,Pad lC PMSS <0-10980'>,,14,Pad lC GMS <0-7575'>,,4,Pad lC MMS <6948-7570'>,,WS#24,Pad lC GMS <0-9600'>,,8,Pad lC PMSS <0-11300'>,,il,Pad lC PMSS <O-17089'>,,12,Pad lC GMS <0-7615'>,,2,Pad lC PGMS <0-9002'>,,10GI,Pad lC PMSS <0 - 8095'>,,18,Pad lC PMSS <0-13910'>,,27,Pad lC 101 Version #1,,101,Pad lC WS lC A2 (VER.1.B),,ll5,Pad lC WS lC D2 (VER.1.B),,ll3,Pad lC WS lC F2 (VER.1.B),,lll,Pad lC 109 B-Lat vl.c,,109(B),Pad lC 125 Version ~3,,125,Pad lC 129 Version ~3,,129,Pad lC 127 Version #3,,127,Pad lC 117 Version #4,,ll7,Pad lC 121 Version #3,,121,Pad lC 119 Version #3,,ll9,Pad lC 131 Version #3,,131,Pad lC WS lC G3 B-LAT (V.1.B),,102(B),Pad lC WS lC G1 B-LAT (V.1.F),,104(B),Pad lC 123 Version #4,,123,Pad lC 133 Version #4,,133,Pad lC Closest approach with Horizontal Plane method Last revised Distance 9-Apr-2001 18-Dec-1998 18-Dec-1998 18-Dec-1998 18-Dec-1998 2-Nov-1998 1-Dec-1998 8-Jan-1999 2-Jan-1998 13-Ju1-1999 8-Jun-1999 4-Jun-1999 24-Aug-1999 il-Mar-1999 17-Dec-1998 18-Mar-1998 18-Dec-1998 17-Dec-1997 18-Dec-1998 19-Mar-1997 7-Jan-1998 18-Dec-1998 18-Dec-1998 22-Feb-1999 1-Jan-1999 12-Apr-2001 12-Apr-2001 12-Apr-2001 12-Apr-2001 12-Apr-2001 16-Apr-2001 16-Apr-2001 16-Apr-2001 12-Apr-2001 16-Apr-2001 12-Apr-2001 16-Apr-2001 12-Apr-2001 12-Apr-2001 16-Apr-2001 16-Apr-2001 105.1 630.7 407.4 304.3 220.4 1018.1 322.0 347.4 23.7 761.7 761.7 819.6 834.5 863.7 717.0 600 8 517 3 11968 5 182 2 185 4 182 5 745 9 134 6 454 6 849 7 29 4 246.2 167.6 194.4 164.2 404.7 464.3 434.9 285.1 345.6 314.5 495.4 44.7 74.9 374.4 524.8 M.D. 121.0 121.0 121.0 121.0 121.0 9105.9 121.0 121.0 356.5 60.5 60.5 196.7 121.0 121.0 121.0 121.0 121.0 121 0 121 0 121 0 121 0 121 0 121 0 121 0 6O 5 121 0 1261 4 1354 7 121 0 121.0 121.0 121.0 121.0 121.0 121.0 121.0 121.0 121.0 121.0 121.0 121.0 Diverging from M.D. 6372.5 121.0 121.0 121.0 10969.0 9105.9 121.0 121.0 356.5 60.5 60.5 196.7 121.0 121.0 121.0 121 0 121 0 6900 6 10969 0 121 0 121 0 121 0 121 0 10869 1 6O 5 121.0 7068.8 6956.7 1757.5 121.0 121.0 121.0 121.0 121.0 121.0 121.0 121.0 1968.8 1230.3 121.0 121.0 Phillips Alaska, Inc. Pad 1C,17 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 2 Your ref : PMSS <0 - 10969') Last revised : 2-Dec-1998 Reference wellpath Object wellpath : Unknown Data,,WS1,Pad lC Horiz Horiz Min'm M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 7595.2 4380.0 4821.8N 2969.5W 4338.3 4380.0 5387.6N 4490.4W 290.4 1622.7 1622.7 Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #17 and TVD from RKB (Parker #245) (102.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 328.79 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company CASING / TUBING / LINER DETAIL 9-5/8" Surface CaSing WELL: 1C-17 KRU DATE: 11/22/98 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS 40.35 65 Jts Joint 'B' Joint 'A' 127 Jts 1 Jt 2 Jts RKB to Landing Ring - Parker Rig #245 FMC Gen 4 Fluted Mandrel Casing Hanger & pup 9-5/8", 40/1, L-80, BTC Casing (Joints #131 -#195) 9-5/8", 40#, L-80, BTC Casing - Baker Locked Gemoco "754' Sta~le Cementing Tool . 9-5/8", 40#, L-80, BTC Casing - Baker Locked 9-5/8", 40#, L-80, BTC Casing (Joints #4 ~ #130) Gemoco Insert Shut-Off Baffle 9-5/8", 40#, L-80, BTC Casing Gemoco Float Collar (Joint #3) - 9-5/8", 40#, L-80, BTC Casing Gemoco Float Shoe (Joints #1 & #2) 2.26 40.35 .2507.85 41.70 42.61 2550.46 2.76 2592.16 38.96. 2594.92 4844.91 37.26 1.45 ' 77.60 - 1.70 Bottom of Shoe ==>> .. TD of 12-1/4" Hole = 7606' MD 2633.88 7478.79 7478.79 7516.05 7517.50 7595.10 7596.80 (~ 1 O' of Rathole) . Baker Lok thru Insert Shut-Off Baffle, plus Stage Collar to Joints 'A ' & 'B' Instafl Insert Shut-Off Baffle in Connection on Top of Joint #3 Run Sto~le Collar & Baker Lok'd Jts 'A' & 'B' on Top of Joint #130 Run FMC Han~ler on Top of Joint # 195 43 Bow Sorina Centralizers: 1 / Jt on first 15 joints, first 2 on stop rin~l in middle of joint; -- , Then 1'every3rdjointonJoints#18, 21, 24, 27, 30, 33, 36, 39, 42, 48, 51, 54, 57, #60, 63, 66, 69, 72, 75, 78, 81, 84, 87, 90, 93, 96, & 99. 2 Riaid Straiaht Blade Centralizers: Slide 1 on Jt 'A, & Jt 'B, .. Leave OUT 10 ioints: #196 thru #205 Remarks: String Weights with Blocks: 310K# Up, 130K# Dn, 75K# Blocks. Ran 197 joints of casing. '- Drifted casing with 8.679" plastic rabbit. Used Arctic Grade APl Modified No Lead thread compou on all connections. Torqued connections to the base of the triangle stamp. · Don E. Breeden Parker Rig #245 Drilling SupervisOr: CASING / TUBING / LINER DETAIL 7" Intermediate Casing ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL: 1C-17 KRU DATE: 10/25/98 1 OF 1 PAGES # ITEMS 1 Jt 1 Jt 249 Jts 2 Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Parker Rig #245 - RKB to Casing Head = 38.40' (Landing Joint 9.26' above RKB) Landing Joint, 7" Casing (Jt #253) 7", 26#, L-80, ABM-BTC Casing (Cut-Off Joint, Set on Slips) (Jt #252) 7", 26#, L-80, ABM-BTC Casing (Jts #3 thru #251) Gemoco Float Collar 7", 26#, L-80, ABM-BTC Casing (Jts #1 & #2) Gemoco Float Shoe LENGTH 42.64 42.33 10379.70 1.26 81.85 1.48 Bottom of Shoe ==>> TD 8-1/2" Hole = 10,540' MD Parker Rig #245 - RKB to LDS on Tubing Head = 36.58' Baker Lock through the Float Collar 20 Bow Spring Centralizers; One on each of first 20 joints, first two on stop rings in middle of Float Joints. 22 Centering Guides: Slip one on every 3rd joint as follows: Joints #186,189 192,195,198,201,204,207,210,213,216,219,222,225,228,231,234,237,240,243,246,24! I Joint #253 will be Landing Joint, expect it to be about 9' up to tag boffom. (Joint #252 will be landed on slips & cut-off after cement job.) Leave OUT 7 Joints (Joints #254 thru # 260). DEPTH TOPS -9.26 33.38 75.71 10455.41 10456.67 10538.52 10540.00 Remarks: String Weights with Blocks: 270K# Up, 145K# Dn, 75K# Blocks. Ran 252 joints of casing. Drifted casing with 6.151" plastic rabbit. Used Arctic Grade APl Modified No Lead thread compou on all connections. Torqued connections to the base of the triangle stamp. Set 175K# down on FMC casing slips (250K# with blocks). Parker Rig #245 Drilling Supervisor: G,R, Whitlock CASING / TUBING / LINER DETAIL 4-1/2" Production Liner WELL: 1C-17 KRU ARCO Alaska, Inc. DATE: 11/30/98 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS . Baker ZXP Liner Top Packer 13.78 10311.81 Baker HMC Liner Hanger 6.671 10325.59 X© 5" Buttress Casing Box x 4.75" Stub ACME Box .88 10332.26 Baker Seal Bore Extension 5" o.d. x 4" I.d. 11.35 10333.14 XO - 4.75" Stub ACME Box x 4-1/2" EUE Pin .61 10344.49 X© 4-1/2" EUE Box x4-1/2" NSCT Pin 1.56 10345.10 18 Jts. 4-1/2", 12.6#, L-80, NSCT (~Jts #3 thru #20~) 556.21 10346.66 Baker Landing Collar 1.14 10902.87 1 Jt 4-1/2", 12.6#, L-80, NSCT (~Jt #2~) 31.09 10904.01 Baker Float Shoe 1.15 10935~ 10 1Jt 4-1/2", 12.6#, L-80, NSCT (~Jt #1~) 30.80 10936.25 Baker Float Shoe 1.95 10967.05 Shoe @ 10969.00 TD 6-1/8" hole = 10969' Parker Rig #245 - RKB to LDS on Tubing Head = 36.58' 40 SDira.alider centralizers: 2/it 20 Stop Rings: 1/jt Remarks: String Weights with Blocks: 165K# Up, 135K# Dn, 75K# Blocks. Ran 20 joints of casing. Drifted casing with 3.833" plastic rabbit. Used Arctic Grade APl Modified No Lead thread compou on all connections. Torqued connections to 4100 ft-lbs Parker Rig #245 Drilling Supervisor: G.R. Whitlock - ARCO Alaska, Inc. Cementing Detail., Well Name: 1C-17 Report Date: 11122/98 Report Number:. 10 Rig Name: RIG # 245 AFC No.: AK9157 Field: Kuparuk River Unit 9-518" 12-114" 62* slant 7597' MD 14381' TVD . 7479' MD · . Centralizers State type used, intervals covered and spacing Comments: ~43 Gemoco Bow Springs: One on each of first 15 joints, first two on stop ring in middle of joint; Then one every third joint thru i joint #99. 2 ROTCO Rigid Sraight Blade Centralizers: On middle of joint on each side of Stage Collar at 2592' MD. Mud Weight: PV(prior cond): PV(after cond): I YP(prior cond): YP(after cond): Comments: 10.4 ppg 38 30I 43 30 I Visc: 98 sec to 70 sec Gels before: Gels after: Total Volume Circulated: 15133 11135 1743 Bbls Wash 0 Type: Volume: Weight: Comments: ARCO Wash 20 Bbls 8.34 ppg 1st Stage Spacer 0 Type: Volume: V~/eight: Comments: ARCO 40 Bbls 130 Bbls water 10.5 ppg 18.34 ppg 1st Stage 12nd Stage Lead Cement 0 T'y~e: [ Mix wtr tamp: No. of sacks: I Weight: Yield: Comments: AS III LWI 75' F 330 sx 1600 sxI 10.7 ppg 4.44 cfs 1st Stage 12nd Stage Additives: ' Class G + 9% D44 + 0.6% D46 + 30% D53 + 1.5% D79 + 50% D124 + 1.5% 51 Tall Cement 0 Type:-J Mix wtr tamp: No. of Sacks: Weight:'l =' Yield: Comments: ClasSG I AS II 75* F 670 sx 160 sx 15.8 ppg 115.7 PPgI 1.17 cfs 10.93 cfs 1st Stage 12nd Stage A-~ditives: Class G + 1.0% S1 + 0.2% D46 + 0.3% 1365 II Arctic Set I Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 8.3 BPM 17.2 BPM 7,8 BPM 17.2 BPM 310K~ {75K~ Blocks) 1st Stage 12nd Stage Reciprocation length: Reciprocation speed: Sir. VVL Down: -15' -20 fpm 130K# (75K# Blocks) Theoretical Displacement: Actual Displacerr;ent: Str. VVt. in mud: 567 Bbls I 196 Bbls 568 Bbls I 197 Bbls 147K# Cemented to Surface Date:Ill22/98 Yes I Yes Yes/Yes Time:13:301 17:30 Rema~s: Circulated to condition hole & mud for cementing. Circulated 1743 Bbls, 8.5 BPM final rate, 600 psi. Reduced funnel viscosity from -100 sec to -70 sec, MW from 10.5+ ppg to 10.4 ppg. Reciprocated casing while circulating, 310K~ - 335K# Up, 135K~ Down. . 1st Stage Cement Job: Dowell flush lines with 5 Bbls water. Test lines to 3500 psi. Pump 20 Bbls ARCO. Wash, 5.5 BPM, 300 psi. Pump 40 Bbls, 10.5 ppg ARCO Spacer, 5.5 BPM, 350 psi. Mix & pump 263 Bbls, 330 sx, 10.7 ppg AS III LW Lead Cement, 7.1 BPM, 300 psi. Load & drop bypass plug. Mix & pump 129 Bbls, 15.8 ppg Class G Tall Cement, 7.0 BPM, 300 psi. Load & drop shut-off plug. Chase plug with 6 Bbls Tail Cement (670 sx total Tail). Follow with 24 ebls wash-up water. Switch to rig pump & finish displacement with 538 Bbls mud, 8.3 BPM to 7.8 BPM, 300 psi to 1400 psi. Slowed rate to 4.6 BPM, 1250 psi to bump plug. Bumped plug & pressured up to 1550 psi. Bled off & checked floats, OK. Reciprocated casing until 10 Bbls before spacers reached shoe, pipe getting sticky about 5' up, pulling a little more each time to pull through next 5', up to 380K~; also losing more weight down. Tried once more up to 400K~, then set down on hanger & left set. Had full returns throughout. 1st Stage ClP ~ 1330 hfs, 11122/98. Pressured up & opened stage tool at 2592' MD, 1998' TVD. Stage tool opened at 2850 psi. Circulated hole clean through stage tool & reconditioned mud for 2nd stage cementing. Circulated 626 Bbls total, 8.1 BPM final rate, 375 psi. Circulated out 60 Bbls of spacers & about 160 Bbls of Lead Cement & cement contaminated mud. 2nd Stage Cement Job: Dowell prime up & pump 5 Bbls water, test lines, pump 25 Bbls more water. Mix & pump 459 Bbls, 600 sx, 10.7 ppg AS III LW Lead Cement, 7.1 BPM, 300 psi. Saw water flush, then cement contaminated mud at 430 Bbls pumped. Had 10.7+ ppg Lead Cement returns at 444 Bbls pumped. Switched to Tail at 459 Bbls Lead Cement pumped. Mix & pump 10 Bbls, 60 sx, 15.7 ppg Arctic Set I Tail Cement, 2.8 BPM, 250 psi. Drop closing plug & chase with 20 Bbls wash-up water, 6.8 BPM, 300 psi. Switch to rig pump & finish displacement with 177 Bbls mud, 7.2 BPM, 550 psi. Slowed to 5.3 BPM, 450 psi to bump plug. Bumped plug. Pressured up & saw stage tool close at 1200 psi. Pressured up to 2200 psi & held 5 minutes, OK. Bled off & checked floats, OK. Had good 10.7 ppg to 11.0 ppg Lead Cement retums to surface (approx. 220 Bbls). Had full returns throughout. 2nd Stage ClP ~ 1730 hrs, 1¶122/98. . i Cement Company: Dowell IRig Contractor: Parker IApproved By: Don E. Breeden ARCO Alaska, Inc. Cementing Details Well Name: 1C-17 Report Date: 11/28/98 Report Number. 16 Rig Name: RIG # 245 AFC No.: AK9157 Field: Centralizers State type used, intervaJs covered and spacing Comments: I Bowsprlng/]t on the first 20 jts (first three centralizers on stop rings rest on collars) Centering guides on Jts 186,189,192,195, 198,201,204,207,210,213,216,219,222,225,228,231,234,237,240,243,246,249 (22 total) Mud Weight: PV(prior cond): PV(after cond): I YP(pdor cond): YP(after cond): Comments: 9.7 19 19I 20 20 Gels before: Gels after. Total Volume Cimulated: 7/8 7/8 800 Wash 0 Type: Volume: Weight: Comments: ARCO Wash 20 8.33 Spacer 0 Type: Volume: Weight: Comments: ARCO 40 12.0 Commonts: Additives: Comments:Tail Cement 0 G Type: Mixwtrtemp: I Nc. of Sacks:I 75 175 Weight: I Yield: 15.8 1.17 Additives: .1% D800, .2% D46, .3% D65 Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 6.3 6.3 270 Reciprocation length: Reciprocation speed: Str. Wt. Down: 25 6 fpm 145 Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 399.4 399.4 Calculated top of cement: CP' Bumped plug: Floats held: 9740 Date:l 1/27/98 yes yes Time:20:15 Remarks:Good returns throughout Job. Able to reciprocate pipe throughout job I Cement Company: I Rig Contractor: IApproved By: DS I PARKER I G.R. Whitlock CASING TEST and FORMATION INTEGRITY TEST Well Name: Supervisor: 1C-17 Don E. Breeden/M.B. Winfree 9 5/8", 40.0 ppf, L-80, BMTC Date: 11/24/98 Casing Size and Description: Casing Setting Depth: Mud Weight: 8.5 ppg Hole Depth: 7,626' TM[:) 7,597' TMD 1,473 psi + 8.5 ppg EMW LOT = (0.052 x 4,381') = 15.0 ppg Fluid Pumped = 5.0 bbl EMW = 4,381' TVD Leak-off Press. + MW 0.052 x TVD Pump output = 0.1000 bps ~..JTIME LINE 3,300 psi]~ I-LLLI-LL-I L LLLI-LLLLLLL[ LL/ LLJ-LLI-J !-~-J L_~,jL~, -~_,JTj~I~)NE MINUTE TICKS ~,2oops!,~,,-,~,,,,,,-,-_~,_,.j,L,.,:-,,.,.,.,:,...~,..,.:-,,,,,,: ..,; .... ; .... ,, 2,900 psi .... 2,7oo psi fl-i-l-t-kfl-f--t~t-t-f--f-t-I-I-~-f-l-i-~-~-~-k,/~J I Itt I I i-t-l-f-l-t-t-l-t-t-i-l-l-l~-fffi-I-~-t-~-I-l-t-J 2,600 psi 2,500 psi 2,400 psi 2,300 psi 2,200 psi 2,100 psi 2,000 psi 1,900 psi 1,500 ~si 1,700~sl ' ' ' ~ ~ ' ' ~ ' 1,600 1,500 psi 1,400 psi 1,300 psi 1,200 psi 1,1 O0 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi 0 2 4 6 8 101214 ~6182~222426283~323436384~424446485~525456586~26466687~727476788~28486889~9294969810101010101111111111121212 st st st si st st st st st st st st st ,st st st st st st st st st ,st st st st st st st st st st st st st st st st st st ,st st st sf st st st st st st 0 2 4 6 8 0 2 4 6 8 0 2 4 k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k st st st st st st st st st st si' sl st k k k k k k k k k k k k k STROKES LEAK-OFF DATA MINUTES FOR FIT STROKES PRESSURE ........................... _O___s_t_k__s_ ............ _o__R_sj ....... ..................... ~, ..... ..4_.s._t._k..s_ ......... !_O__~___R.s_i. ..... ........................... ..~_?__t._k~. ......... ~.~J___p._s.[ ..... .......................... J~_?_!.k~ .......... .4._3..~.__P.?.L ..... .......................... ~__6__s__t__k.s_ ......... f_?__O___p__s_[ ..... .......................... _?.O...s..t..k.s._ ......... .7J._6___p..s.i_ .... .......................... ._~.4_..s.!.k?. ......... .8_.2.9.._P._S)_ ..... .......................... ..2_8..s..t_k_s.. ......... ?_.4..2_._p..s.[ .... .......................... ._3.2._.s__t._k~_ ...... ~_,_o_§.2__p._sj .... .......................... ._3.?_.s_!_k_s- ........ ~:~.o.~_.p__sj__. ........................... . _4. 9_ ~_t. _k~ ........ ~_,~_.p__sj .... ........................... ._4_.4_.s__t._k?_ ....... ~_,.4_~_s__p_.sj .... ........................... __4~__s_!_k_s- .... +__~:_4_~_o__p__sj__. ' ..................... '~ .................... i ..................... ~ , CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ........................... _O___s_t_k__s_ ............. _o._L)__sj ....... ........................... _.4__s__t__k_s. ........... _t_~.f...p..s.i_ .... ..................... ~ ..... _.~_~_t_k_~ ........... _~._s.9_._p__s_i- .... ......................... J.?_.s.!k__s- ......... _.4._S._O_._p_.s_i_ .... .......................... J.6__.s__t.k__s_ .......... _6__O._O_._p__s.i_ .... .......................... ~.O..~_t.k_.s. .......... .~._O..O_._p__s.i. .... .......................... ..~_4.__s._t_k__s_ .......... ?._S._O___p__sL .... .......................... ~_8..?..t.k.?. ........ j.,j..o__o__R.s.L.. ........................... .3_.2__.s_.t.k_.s_ ........ j:.2_Z~__p..sj... .......................... ._3~_~_t_k_~ ........ j_,.4_.s..o..p..s_L.. ........................... ?__o._~_Lk_~ ........ j_,.6_~_p_.sj__. ........................... . _4_.4__s__t_k_.s_ ........ j.,.8_~_s_.p_.sj__, ........................... .4__.8_~_t_k_?_ ........ .2_:O_.2__5__p.sj__. ........................... ._5.?__s_!k_s_ ........ .2..,.2_ ~.5...p..sj ._. .......................... .~._.6..s..t_k_.s. ........ ~:.4_.o..o..p..s.L.. i ..................... ! .................... ~ .................... i ' . 60stks ~ 2,625 psi ! ..................... ~ .................... 'J ..................... J L ] 68 stks j 3,025 psi ! SHUT IN TIME! i ..................... ~ .................... ~ ..................... i i ..... -6?6--r~iF; .... ~ .................... !'---~-:6'~§-~i--' j ...... f.-~--r~i~ .... i .................... T---~;~i~iJ-i:;~;i--' jSHUTINTIMEj SHUT IN PRESSURE j 3.0 min i j 1,970 psi ! ...... ~:-~--~ .... ! .................... ] .... ~-:z~-~--~r--j ..... -~:-~--~i~ .... i .................... i''-'~;~-i~;r'- ! ..... '~:'6",~i~; .... i .................... i-'q;~Ti:;~;i'--! ! ..... -~:'~--,~i~- .... j .................... i"-'~;~;~-i:;~;i"- ..... -~-.'b--~ .... ~ .................... ]-'--~;~-i~;i---j ..... -~:-~--~i~ .... i .................... ]'-'-~;~;ii~-i~;i--' i -~:-~'-,~i~; i ..... .... .................... i ~f~"~,-~-f i i ..... .... ..... -~-.5"r~T;; i .... .................... i"--~;~5-i:;~i--' [ ..... ~-.-6--ri'ii~ .... ] .................... 1 ..... ~i?6"l;~'i .... [ i ..... 5T6"r;'iik' .... ~ .................... i'"'~-i:;~i'" 11.0min ~ : 875 psi lO.Omin : : 1,930psi ',Ziii~Z~_]~i~Z]ZZZZZZ]]Z]~,)]~ZZj ..... f~:~--r~;~----i .................... ~----~;~ii-i:;~i--'~ 20.0 mini i 750 psi , "'"'~'~'~i~'"'! .......................................... ! 1,910 psi .... .?_5...9..m..!n_._: .................... ~ ..... Z_~__o_._p..s.i_ .... , : ..................... : .................... i'-'i~666'~i'"' ...................... : .................... ~ ..................... ' :.____2_.5__..o__._m.!_n____,, .......................................... ..... 9.o__.9_.m__!n_____! .................... .: ..... Zg._o_._p..s.i_ .......... 99_..o__..m. Ln___.i .................... j___ j:~.o__o_.p..sj_.. NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 1C-17 Supervisor: G.R. Whitlock 9 5/8", 40.0 ppf, L-80, BMTC Date: 11/25/98 Casing Size and Description: Casing Setting Depth: Mud Weight: 10.9 ppg Hole Depth: 6,344' TVD 7,597' TMD 4,381' TVD EMW = Leak-off Press. + MW 0.052 x TVD 254 psi + 10.9 ppg EMW LOT = (0.052 x 4,381') = 11.7 ppg Fluid Pumped = 3.4 bbl Pump output = 0.1000 bps ...~TIME LINE 3,3003,200 pslPSl t-d-f-P4-f-t-t-l--l-t ........... _Lj_j~U_L~I_~_L_[_LL_LLIF;, trT[~ ,~,~ ~ ,__~_,~7~-~1 ~ ~N,E, MINUTE TICKS 3,100 psi ..........__; ................ ttL ] ]iI iJ.JJ.L.Lt.J..L.L£.Li..L.i .... ii- iI I ~ I ~ I I · 2,900 psi-k-tlllllllll 2,8oo psi-f-l-fl t I I I I I I 2,7oopsi ~ ~ ~ ~ ~ ~ ~ ~_~ 2,500 psi -- 2,400 psi 2,300 psi -H-i-H-t-H-t-t--I 2,200psi ' ' ' ~ I 1 I I/11 I1 2,000 psi 1,900 psi ],800 psi -t'-~-~'-~--~'-~'~--~--~--~- ]200 psi '~-~-I-f-~--~-~-h-[- 1,600psi-~-H--I I I I I I t 1,500 psi ,-, 1,400psi I t I I I I I I j I 1,300 psI J-M-I I t I I I I 1,200 psi ~, 1 oo psi ~H-k-H-½-H~- ],ooopsll I I I I I I i-I-f-' 900 psi 800 psi 700 psi 500 psi -l--h-I-I--t-I-A~'-t--f- 400 psi -[-f-t-l-t--J~-I-d-t- 300 psi 200 psi - - ]oo psi 0 psi 0 2 4 6 8 10 12 141618 2~ 22 24 26 2~ 3~ 32 34 3~ 38 4~ 42 44 46 48 5~ 52 54 56 58 6~ 62 64 66 6~ 7~ 72 74 76 78 8~ 82 84 86 88 ~ ~2 ~4 96 ~}8 10 1010 10 10 11 st st st st st st st st si st st st st st st st st st st st st st st st st sf st st sf st st st st st st st st st ,st st st ,st ,st ,st st si st st si st 0 2 4 6 8 0 k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k st `st sl st sl st k k k k k k STROKES LEAK-OFF DATA MINUTES FOR FIT STROKES PRESSURE ............................ .o_._s_tk_.s_ ..... i ...... .o__g_sj ....... 2 stks i 45 psi L .....................~ .................... J ..................... 4stks i 120psi ~. .................... .~ .................... ~ ...................., 6stks ! 160psi : 8stks i 190psi .......................... J._2_.s._t_k.s.___.L .... .2__1._4_._P._S! .... ,. .................... , .... J..4_~_t..k~ .... j ..... ~.%o..e.7! .... j ......................... .!.~_.s_.t._~.s.___.i .... ~_~.?_._R_s! .... 18stks i 232 psi ~ ..................... ~ .................... .~ ..................... 20stks ! 235 psi L .....................~ .................... .~ ..................... j ......................... .-~_?.-s--t-~-s- .... i .... ~-3.-6_.-P_-S! .... 24stks i 243 psi ...................... ~ .................... -t ..................... I i 26stks i 245 psi ......................... -~'Ea-k'~ .... T .... ~;;~-f'~-~-f .... ........................... ._3.9..s._t _k_.s.___J ..... _2__4_.s_._P_.S! .... .......................... A?__s_.t~.s. .... i ..... _%~_?._e._s.i. .... j 34stks ! 254 psi i CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ............................ .O__s_j.k_.s. ............. _o._p__sj ....... ........................... _.4__s__tk__s_ ........... .L2..5..e__s! .... ........................... _.~__s__t_k_s_ ........... _2._5._o..e._s! .... ........................... j.2__.s_.t.~__s_ .......... .4..s._o_.e_.s.i- .... .......................... J.6._.s__t.k__s_ .......... _6._o._o_.e__s! .... .......................... .2._O.__s_.t.k__s. ......... __S._O._O__.p__s! .... .......................... .2..4.__s..t_k._s. .......... _9._S.9___p_s..i- .... ,. .................... , .... .2_A_s__t_k__s- ........ j _,.1_.o_ _o_ _ .p_ .sj _ _, .......................... ._%2_.s..t.k._s. .... j_._J_,.2_.'r__~ ~..s_L 36 stks 1,450 )si , ..................... 'r .................... '~ .................... '-, .......................... . .4_.O__s__t_k_.s_ ........ j _,.6_.2__s_ ...~_.si_" ........................... ._4_.4..s._t_.k.s. ........ !,§~.5__?..si.' 48 stks 2,025 ~si 56 stks 2,400 ........................... _6__0___s__tk_.s_ ........ _2_,_6__2_~ _!s_L ......................... _6_.4___s__Lk_.s- ........ _2..,_8j_ .0_ _ .p_ _sj _ _ _ ........................... .6.&.s..t..k.s_ ........ ~_,_0..2..S_..p_ _sj _., SHUT IN TIME ...... .0_:.0..._min_ ............................................... 1.0 min SHUT IN TIME ..... .9:.o....m_j_n. ............................... _2_.5__4__p..sj ..... ....... P...m..!n._ ............................... !f._~._e..s! ..... ..... &.o...m. in. ............................... !_4__~__e._s! .... ..... _3_:_o.__m.!n_ ............................... !.4..4..e..s! ..... ...... __4:_.o__.m!n_ ............................... !.4._O_.e..s! ..... 5.0 min ~ 135 psi , 7.0 min i 130 psi ! 8.0 min ! i 128 psi ...................... I .................... I ..................... 9.0 min j i 125 psi ..... ].O....O._.m._!n.....i .................... J ..... .1_ _2. _4..e_ .s_i_ ..... i i 2.0 min SHUT IN PRESSURE 3.0 min , ..................... ~ .................... 4.0 rain 5.0 min ~ ..................... , .................... 6.0 min 7.0 rain i ..................... .~ .................... 8.0 min , 9.0 min i ..................... ~ .................... 10.0 min 15.0 min 20.0 min , , ...................... t ........ .... ~:~_.,.,_,,::___~ .................... : ..................... ..... P.:.°._.m._!n____.i .................... J .................... J NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. Trantham Phone (907) 265-6434 Fax: (907) 265-6224 May14, 2001 Commissioner Cammy Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval - 1C-17 Application for Annular Disposal Dear Ms. Commissioner: As per AOGCC regulations 20AAC25.080, Phillips Alaska, Inc. is submitting this Application for Sundry Approval for annular disposal in the' Kuparuk well 1C-17. Also submitted with this application are attachments to meet the requirements for annular disposal as stipulated by AOGCC. If you have any questions regarding this matter, please contact me at 265-6434 or Mark Chambers at 265-1319. Sincerely, J. Trantham Drilling Engineering Supervisor PAl Drilling JT/skad MAy 1 5 2001 Alaska Oil & Gas Cons. Commission Anchorage NOTE TO FILE Request for Annular Disposal Authorization Kuparuk 1C-17... 198-224... 301-128 An application for Annular Disposal (AD) approval for Kuparuk well 1C-17 has been received. This well was spudded 11/15/98 and completed 12/02/98. Two previous applications for AD have been made for this well. The original application for AD was made on 12/4/98 (403-398-325). That application was denied 12/23/98 with Blair writing the following comment on the form, "FIT does not confirm shoe is adequately cemented." A second application for AD approval was made 12/15/98 (403-398-339). That application was supplemented with additional information to correct some graphical misleading information on the odginai application. The data for the 9-5/8" casing test is confusing and appears to include pressure information prior to drilling out the stage tool as well as the ultimate pressure test at the float collar. Additional information regarding the "pump in" test was provided late in February. The injection pressure plot indicates a steady pressure of about 1400 psi. The rate is not given. When pumping was completed, the pressure declines to about 1000 psi, which is similar to when the slope of the pressure plot changed when initially pressured up. The subsequent application for AD was approved 3/18/99. It does not appear that any AD has been conducted in this annulus. In the latest AD application, PPCo has provided information in the "expanded" more complete format that we are requiring. There are no other wells within ~ mite of the surface casing shoe of 1C-17. They have provided a different work product to illustrate that no other wells are in the vicinity. They employ a computer search of their directional data base look for wells within 1000' to 2000' radius and provided a plot of a traveling cylinder. The cylinder plot is confusing and small scale. The only wells that appear in the computer scan are 2 future WS wells. These 2 wells will have their casings set in the West Sak above the confining intervals and should not be affected by the disposal in 1C-17. Based on the information provided, I recommend approval of AD in Kuparuk 1C-17. T. E. Maunder, PE Petroleum Engineer Annular log i -~ I AnnulerD~s~osa~rova~Log -l'-- ! ----? .......... Original Subsequent AOGCC ,In PTD or Sundry Sundfy ,letter Final Well Final Total Sundry Completion Approval Approval LOTICMT Approval Report File Report Volume Operator Field Well Name ,Approval ;Permit# :)ate Date Dates Results , (Y/n) (),In), (y/n) Date Injected Comments ...... BPX IU 1-03tP-16 PTD N/A N . N __ 0 qever ut01zed BPX PBIJ 11-38 SUN /96-189 1t/19/97 ;Y 0 Never utilized, no sundry filed .BPX DIU 1-19/I-18 ~TD 95-093 8/17/95 'N/A .... --___ ' N N 2/28/97 8,960 Approval fax from BEW; from BPXA 1995 & 1996 con'ected summaries ,BPX DIU 1-23/O-15 PTD 94-128 1/13/95 NIA N Y Y 2/26/97 32084 From BPXA Annular injection Data Entry_ Screen; from 1-53/Q20, 2-40/S22, 1-03/P16 AA---~ PBU 12-35 =TD 95-130 10/27/95 N/A ~-- __ Y__ Y_ ......... _2/~__96 ...... 37~23 From BPXA Annular Injection Dam Entr~ Screen -- AAI PBU 12-36 "TD 95-158 11/21/95 N/A N Y Y 2/28/97 4002 from BPXA 1995 & 1996 corrected summaries BPX DIU _ 1-33/M-23-- PTD 95-107 10/4/95 N/A ; N Y_ N .....-_._-._-~,_-~2~2~§_-.~ ~i.__~98_79 Letter approval fax; surface broach; volume from BPXA 1995 & 1996 corrected summaries AAI pBU 13-36 PTD 95-167 12/24/95 N/A N Y N__ ........2_/~_~7_ ......... 4_13_~7from BPXA 1995 & 1996 corrected summaries AAI -- I~B-~ 14-44 =TD 95-103 9/15/95 NIA .................. N ____Y_ ............ 1_2_/1~4/9~8 ..... _3._9_7_4. From BPXA Annular Injection Data Entry Screen AAI PBU 15-42 :~TD 95-185 1117196 NIA N N .___ n/a 0 Never utilized AAI PBU 15-43 PTD 96-083 5/25/96 N/A N N n/a 0 Never utilized AAI PBU 15-45 -- PTD 96-069 514196 N/A N Y Y 7/2/96 1882 Broach to surface - downsqueeze annulus 5/5/96 AAI --- PBU 15-46 PTD 96-061 6/20/96 N/A N N n/a 0 Never utilized .......................... AAI PBU 15"47 ~TD 95-174 12/8195 N/A N Y N 2/28/97 3002 from BPXA 1995 & 1995 corrected summaries ....................... AAI PBu '1-~,~ ............... ~TD 95-208 3/11/98 N/A N Y Y 4/11196 ........ :~.3.__8,~...:Fro____m. BPXA Annular Injection Data Entry Screen AAI PBU 15"49 PTD 96-034 4/7/96 N/A N Y Y 2/28/97 4669 from BPXA 1995& 1996 corrected summaries §PX ~1'0---- 1-59/O-24 PTD 96-022 2/21/96 N/A N N n/a 0, Never utilized ~Px D~U 1-6UQ-20 ~TD 94-14212/16/94 ,IX------ N Y.... _--~_._-i;_-_~,-~/'~__~J9'~-_ii';iiiii'~;S~,-_2~ FromSPXA Annulet ~n~.o_~a_~_.Ent,LS_c..~e~;_fj_o_m.~8~J~.,_l_~l_N_.2.[ a>~- ..... _0-F_K.-Z ;~_~_~'~N-2--~L-__-~-_-_'L"_~_~-_.,-~ ~-5_~-~8-~_--_' ;i.'_/2__,~ ..... h-/X ........................... ~ ....... N n/a 0Never uti,~ed AAI PBU 18-30 PTD 95-091 7/26/95 N/A N Y ........... :12/--~4-/~ .......... ~-266 From BPXA Annular Injection Data Entry. Screen ~A~ P~U : 18-3~ PTD --- 95-1099~ .... ~X ........ N ..... ~LT_--_-~ Zi'.~_-.;';'iZ~_~i~i~_ ::::::::::::::::::::: From ~PX~ ^nnu~,r ~q~_ection Data Entry Screen AAI PBU = 18-32 ~TD 95-124 10/5/95 N/A ~N Y Y . 1/5/96 3311 From BPXA Annular In_j.ection Data Entry_.S_c_.[_ee_n_; fro___m__l.~-_32~ .............................. AAI PBU 18-34 PTD 95-164 12/4/95 _N/A .................... _N_ ........_N ............................................. ._n!.~ .................. 0 Never utilized Unocal GPT 18742 28RD2 '5~---- 95-077 '~16/95 N/A N N ............................................................................................... AAI KRU 1C-11 SUN 96-172 1714/97 11_!_8/_~___ .............................. y .......... _¥ ................ Y_ ................. E_9(9~ ............ :~4.9~5_. ~'r__o.m___AZ,~_r_epor[ s__u_b_m_l_t_ta_~..2.~9._9_ AAI KRU lC-12 5~-D 96-1-77 1/29/97 _ _ N/A ......................... _Y__ _ ..Y. ........... _Y_ ................... ..4.~9 ........ ~_.5__0~J_5 _f.r.o__~.._A~_!_r_e~oo__~._s_ub_m~_ed .~f_9.-9 .............................................................................. AAI ~"~-0-- ;1'(~:i-~- ................ ~5~'1~ .... ~)~-~-~-1--'-~-~" - '~IA- ~ '_~__ Y Y_. ................ Y_~_' ..... ._4/_9./9___99 ............ ~>._9~.0 fr__o_m_AA__~l.m..~__port submitted 2/26/99 AAI KRU lC-14 PTD 98-017 3/17/98 N/A Y N N .... contingent on data submittal, data not in welt fil.e._~ FIT to 16.0 .A__A~ ...... *R~;~.~¢~:.ii~._--~i_.--'_---~--~.;_._--_' S_U_N_ ........ '98__-_2_4_~___L2/_~J~ ..................................................................................................................................................... _0__h~.~_re_~_e_m_s_b_mac__hLn~o~__~_0_3 ~n w____e_~_L~.e ........................................ AAI KRU '1C-17 PTD 98-224 12/2/98 .3_/.!--81.9._9_ ................ 1_4._9_,_1..4:.1_..._N_ .................................................................................................. _c_o_n_t.i_n_g~___nto___n_.l_0..-4,_03_~a.n__~_u..l.a_r_.._d~.ni___e_d 12/231~9.8_,._ap_proved 3/18/99 ~_-Y'-~ ~R~_U.~ ~;~i!;~_~.'~_-_"_-~;_- ...... §0h- .... 6~:b0-~- 4/2/99 ~!~_~_./_~_~ ............... L~.~_ ............................................................................ ~p_~_,£# ~-070 AAt KRU 1C-21 SUN 99-013 ....................................................................................... . _E?_!~_d__P_TD ~,AT ......... '~R-u-"'~c--~ ......... SUN ~-~-§;4--'- '5'~'~D'~ ...... 5/28/99 ........... 34570 i'rom AAI lO/5199mp_o, rt,{ettera~rovaltoex¢eedvoiumelimltf~rantedS111199 PAl KRU 1C-123 .SUN ........................................................... W_/~'_9_quest later-info not E.ro._v.!.d_e_d_ ...................................................... ~,,~,} .......... ~-I~-0'"""' ~0-~ ...... SUN 98-065 6/3/98 7/7/98 Y .Y Y 10/5/99 32640 from AAI .re~__ submitted 2/26t99 .AAI ..... ~'0---i~'~'4-b ............. 57-D------~-~:4¥-'~T'i'Z-9~T--- ~Ti .......................... ~'- ............. ~'7 ........... ~ .............. '7-~-/9-~ ....... '~-Y:~ ;:0~iT~.~-~'on ~'~ ~,7~-~;F~-7~7.~i-~,e', ~rom AA~ ~rt s,,b._m_~_d_~!~_S_ ........................................ AA -~1~-0--'-1-1~:i'~ ................ SUN 99-072 '~0/26/99 235 w/re.~est later-info not p_rovlded ~i- ...... ~i~-0- ;1-D-~i-~ ..................... ~'kTh-- .... 6~-4--' ~2-0~ .... ~2-9-~-~ .................................... 'iq- ..... ~i ............ ~ .................... ~T)i~'~'iS6 ......... '~5-~-9-~" ~/~-~-i'~S)~-~'~?~-~'7';;[~-~7~'~j~- ~-A-i ........... I~'-0-- 1 D-14 §'ON _9_9-08____-9 ......................................................................................................... 3__55_0~_. notified commission of exceedence, from PPCO 10/13/2000 ~yart___erl__y._re__pg_~_~_ PA KRU 1D-140 SUN 200-136 ~A-i-- ..... ~-5' 15-30'- ........ ~-0~'-- ~-b-~:~;~- ..................................... : -3-~'~- i~ ~-P-c_~'"~9/-~6~1 _q~i~i~' _ .... . ........... .... ~:~-i'-~;-jT;i~-0'~i'-'_~i~;~-_'~'.L_--__~_--_- ~-~ '~'-~'~ ............................................. --_7'_-----£i'; ........... ;~iii';~ii;-£i Z;i;'~-:::::::::::::::::::::::::::::::-_--~i ~'~?_~-~~-.~_~,t. ~,i~?"'~b;~-~ PAl KRU 1D-34 SUN 200-143 32233 LOT to 13,1, 11.4 for annular. Sund_ry a_.l~roval ~00-280 ~_7,~_ ~-_-Z i F.~_~L-:; _~_D-_ ~ ............... ~___ ~t~_~_ "i _--/_-'_~ .-7.;_-~ ;~) ~?~.~_--'_-~ T--'~'--__--. -~_ 'F_~ .-Z ~-'_~-"~ "_;ii; i~-__--._~ 111.-_-'2 L ;'~"; ';;.T-' ;i';i.i L~; ;' Z.--_TZ;_-'_; .... -~_2_'~i ~.r_'~'~~_-~_~-_~ ~_~_~ ~z~ F~ rf PAl KRU 1 D-37 SUN 200-204 W./_r_e~juest when well comp~.t..e_~ ................................................................... ................................... lost rtms during cmt'g, found TOC '740', top job. LOT @shoe 14.9, deep test 13.5; total from PPCO PAl KRU 1D-38 SUN _ 20Q:0_7.7__ ...... 7./2_~_0_0. ............................................................................................................ _~34_0.0_.7' .~...0.~.l_3~00_0_..~.a__ffe_~_re._p_~.~t. ..... PAt KRU ID-39 SUN 200-216 _ w/reguest annular at later dat.e_-not w/ptd., PAl KRU 1D"40A SUN .w/re§uest annular at later dare-not w/~td.. _ _ Page PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Wells Group 700 "G" Street Anchorage, Alaska 99501 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 May 22, 2001 re: Permit for Annular Disposal, Well 1C-17 Tom: As an additional attachment to our request for authorization to use KRU Well 1C-17 for annular disposal, please find following: · a copy of the original chart record of pressure test of the 9-5/8" surface casing, showing a successful test at 3000 psi. and · a copy of the original chart record of pressure test of the 7"x 4-1/2" production string and liner, showing a successful test at 3500 psi. Please call should you have any further questions or needs for additional information. Thanks kindly, Steve McKeever West Sak Drilling Engineer ! ~ .'1' 0 ,..~ ,~,---~ ,. % '~ ~ ~ ~ 0 Ft I I_1--11~ G S ~::: I=! L~ I r- ~:: S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 1C-17, AK-MM-90016 March 11, 1999 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention off Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1C-17: 2" x 5"MD Resistivity & Gamma Ray Logs: 50-029-22872-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22872-00 2"x 5"MD Neutron & Density Logs: 50-029-22872-00 2" x 5" TVD Neutron & Density Logs: 50-029-22872-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia REC 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company Im Ft I I_1_ I IM (~ SEE F:! ~J I I-- I~ S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Cormn. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 March 4, 1999 MWD Formation Evaluation Logs 1 C- 17, AK-MM-90016 1 LDWG formatted Disc with verification listing. APl#: 50-029-22872-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING ANI} RETURNING TItE ATYACltED COPY OF THE TRANSMITTAL LETrER TO TI:IF, ATrENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECF. iVED Date: ''!AR 0 9 1999 ~}as~ Oil & Sas Co~s. C0mrr~n Signe~' 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company ' I-Y.O-~ ,_3- WELL HISTORY HAND03~,~~, Well Workover To Production APl # _...b"~.2_9.-.22872-0_0.._ New Well ... XX To Drilling PTD# 98-224 Comflletlor~ Date 1213/98 Rig Name WELL INFORMATION glTI=' lAP DAP BI-IP /Depth / Date t Inst, I o I'i'0 1%" t I Des~rlptio~ Welgh. t{pp~) Approx D_epths Pa~rnu~d [~iesel/.,.F,..hW~.r 16.s/s,34 12200'/~0310' ] Tubing fluid Ime~l/FW'! Mud 16,8 / &;3,~ / 12,5[~'/lm,v/~ . DIRECTIONAL.INFORMATION RKB 36,58' KOP 250' Av~ Hole Angle 49.7'4 Max angle o/ 84.73 ~ 2967' HMe Angle ~ TD 20,42 I~,,.I~LA~ OR RE..PERFED INTERV&L8 Bet SPF Gun Type ...... Date AFE Number AK9157 F;;rker ~Rig ~245 DOWNHOLE_INFORMATION Drillers TO 10~969' PBTD/Top of fill o,' Junk: ..1._0~.9q.~.3.. Date Tagged__~ BI:~/Installed ~ IA VR Plug 2 Way Check DA VR Plug Downhole Plug F,,ASING/'RJBtNG D/kTA Depth Siva Wt, Grade Conn. Top Bet Cond. 16" 62.51~ H-4D Welded {7 121' Surf, 9-5~" 40~ L-80 BTC O' 759r Prod, T' 26# L-80 BTC-MOD 0' 10540' ,, Liner 4-112" 12.60tt L-80 NSCT 10321' 10969' Tubing 3-112" 9,3# L-80 ABM-EUE 0" 10342' KN~NN Communication Tree W,K,_M.~FMC Gen 4, SK~ _ Tm Cap Corm Otis Union (Type/Pressure Rating) 'l'bg Hgr Conn 3-II2" EUE COMPLETION INFORMATION Item Model VIv Size OD ID Valve La,Ch 512' .,..N.~PPL~ "c~6b ~ 4.4~o' z,12- 102,29' GLM _C_.A~I. COMMM 1;.1/Z' 6,018' 2,920' DV .,R_K. 1o.:i[7.7~ NIPPLE CAMCO ...... D . 4.470~" 2.750" 10316' LOC BAKER _. GBH-22 5-1/8" 2.99~' ,_ 10317' ~.S$.als BAKER GBH-22 4" 3" 10342' M~$, ,, EtAKER GBH-22 , 3-15/16" 3" ...... :Baker Locator/~...e.~'.'~,sembly ~. stabbed I~0~$BE below finer hanue~. ....... ~ ~, .._ ,.,,... ............ .. ~.,. ~ ........ ,..r, , ._,, ...... , ~ ............. · · Rig released subsequerff to full wall complelion as required on State Drilling permit: ~, Yes NO if no, specify remaining operations: ENVIRONMENTAL Location d~an. GENERAL INFORMATION 9-5/8" x 7" Annulus was flushed wilh 300 Bbls of water & fTeeze protected w/Ih 70 Elbls of Diesel - DO NOT BLI~ED OFF !l! Tested tubln.q, Hq.err seals, & anpulus to 3500 psi. Installed Xmas tree and tested to 5000 Pst._~L~_ Title Drilling Supervl_~or Date 12/04/98 · ARCO Alaska, Inc. ,--,.~ it .... °ARUK RIVER UNIT ~ik, WELL SERVICE REPORT 'RP' K1(1C-17(W4-6)) "WELL JOB'~COPE ' ' JOB NUMBER .... 1C-17 FILL: TAG, CL. EANOUT, BAIL .... 1215982055.4 DATE DAILY WORK UNIT NUMBER " 12/18/98 PRE PERF DRIFT/TAG, P/'r TBG 3437 DAY OPER~:I'ION COMPLETE I SUCCESSFUL "' KEY PERSON SUPERVISOR .... I .... (~) Yes O NoI (~ Yes (~ No HES-OBER SCHUROSKY FIELD AFC# CC# DAlLY'COST ACC01i;/I COST Signed ESTIMATE AK9157 230DS10CG $2,115 $15,785 Initial Tbg Pre"ss Final Tbg Press Initial Inner ~,~n Final Inner Arvn '-I Initial Outer Ann ~' Final Outer Ann ., 0 PSI 450 PSI 0 PSI 0 ,PsIj 250 PSII 250 PSI DALLY SUMMARY P/'r' TBG 2500 PSI, OK. TAGGED @10894' RKB, TBG DRIFTED TO 10894' RKB W/~'2'X 2_5" HC DUMMY GUN. [PT ! .~bcj-Csg, Tag] I TIME LOG ENTRY 07:00 MI/TGSM- RIG ON PAD. MUSTER AREA. SLIPS, TRIPS & FALLS. COMMUNICATION. 07:15 08:1 $ 08:45 RU- HES & LRS. 1.875" RLR STEM TS: RS,QC,3',3',3',KJ,SSS,QC. REDRESS STUFFING BOX. F/T LINES & EQUIP 2500 PSI. P/T TBG. LINER- SEALS TO 2500 PSI (1 BELL) SOLID 15 MINUTES, BLEED BACK TO 500 PSI. RIH W/2.60" TEL ASSEM; TT @ 10321' SLM (10342' RKB-- 21' CF) TAG @10873' SLM (10894' RKB) POOH. 10;15 RIH W/22'X 2.50" HC DUMMY GUN; DRIFT TBG 'rD 10873' SLM (10894' RKB) POOH, NO PROBLEMS. 12:00 RDMO TO 1Q-21, TURN WELL OVER TO DSO. SERVICE COMPANY SERVICE DAIL~;'COST ACCUM TOTAL APE; $6:00 $5,000.00 ARco ......... $o.oo $400.00 DOWEI"L ..... ' .... $0,00 $7,070:~'0 HALLIBURTON " '41,00(~00 $1,000.00 LI; rLE RED " .. $1,115.00 $2,315.(~) TOTAL FIELD ESTIMATE , 1/11/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12216 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia 1 C- 15 STATIC PRESS/TEMP 981230 1 1 1 C- 17 SCMT 981224 1 1 1 C- 17 SCMT 981224 1 1 1Q-07A GR/CCL/TEM P 981212 1 1 SIG~_~_~'~ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. REOEIVEE,. DATE: Alaska Oil & Gas Col]s. Anchora.ge STATE OF ALASKA ~.~SKA OIL AND GAS CONSERVATION COMMISSION ¢ RECE ED WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well JAN 12 OIL ~-J GAS ~] SUSPENDED J~J ABANDONED~] SERVICE [~1 ............ ~J,e~9.Er 2 Name of Operator 7 Permit Number Alaska 0ii & Gas Cons. ARCO Alaska, Ina 98-224 6nnhnrnn~. 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22872 4 Location of well at surface~~-~~-~ 9 Unit or Lease Name 1395'FNL, 563'FWL, Sec. 12, T11N, R10E, UM ; :;':' ' ' :' ~ ~'~'~ I Kuparuk River Unit At To pProducing Interval //~_~_ ':'~,~. ~ 10 Well Number 23' FNL, 1830' FWL, Sec. 2, T11N, R10E, UM ; ........ ~ , ' ' ~` 1C-17 At Total Depth : ~' ;~_~ :~.._~:~_'Z'_%7:? 11 Field and Pool , 72' FSL, 1802' FWU Sec. 35, T12N, R10E, UM ' ~ ' KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. Kuparuk River Oil Pool RKB 41', Pad 61'I ADL 25638 ALK 463 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 16 No. of Completions 15-Nov-98 30-Nov-98 02-Dec-98I NA feet MSL 1 10969' MD & 6757' TVD 10903' MD & 6694' TVD YES ~ NO ~ NA feet MD 2208 APPROX 22 Type Electric or Other Logs Run MWD/ReslGR/Den-Neu, CCL 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5# R-3 SURF. 121' 24" 9 cu. Yds. High Early 9.625" 40# L-80 SURF. 7597' 12.25" 1) 330 sx AS III LW, 670 sx Class G 2) 600 sxAS III LW, 60 sxAS I 7" 26# L-80 SURF. 10540' 8.5" 175 sx Class G 4.5" 12.6# L-80 10312' 10969' 6.125" 112 sx Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 10342' N/A 10690'-10720' MD 6495'-6523' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10690'-10720' 4868# of 20/40 sand 27 PRODUCTION TEST Date First Production IMethod of Operation (F'owing, gas 'A, etc.) Injector UNiLfiNA Date of Test Hours Tested PRODUCTION FOIOIL-BBL GAS-MCF WATER-BBI CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBl. OIL GRAVITY-APl (corr) Press. 24-HOUR RATE: 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A 99 ommisslon Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 9. I~o. I 9. - - 130. , GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 10685' 6490' Top Kuparuk A 10969' 6756' Annulus left open o freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ./~,,~ ~. ~ Title ~-,..¢.'~rl~'"("~..,,, L~DATE 4 ~,(I,(~ Prepared ~y Na([;~/Number Sharon AIIsup-Drake/263-4~'i2 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in~situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. f "-' KUPARUK RIVER UNIT ~ WELL SERVICE REPORT ,~' K1 (1C-17(W4-6)) WELL JOB SCOPE JOB NUMBER 1 C-17 RIG WORKOVER, WORKOVER SUPPORT 1223981612.1 DATE DAILY WORK UNIT NUMBER 12/24/98 OBTAIN CMT & PERFORATE DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 1 NO YES ALLDREDGE JOHNS FIELD AFC# CC# Signed ESTIMATE 999153 230DS10CG InitialTbgPress FinalTbgPress Initial lnner Ann Final lnner Ann IlnitialOuterAnn I Final Outer Ann 0 PSI 0 PSI 0 PSI 0 PSIII0 PSI 0 PSI DAILY SUMMARY OBTAINED CMT, GOOD CEMENT BOND IN LINER. ATTEMPTED TO PERFORATE 10,700' TO 10,720', PERF GUN DID NOT FIRE. RETURNING IN THE A.M. TO PERFORATE.[Perf] TIME LOG ENTRY 10:00 MIRU E-LINE, HELD SAFETY MEETING 12:00 RIH WITH TOOLS INCLUDING, TEMP., MANOMETER, CCL, CBL- MAP, OBTAIN CEMENT BOND LOG IN LINER FROM 10918' TO 10678'. POOH 17:15 RIH WITH GAMMA GUN TOOL AND 20', 2.50" HALLOW CARRIER 4 SPF BH PERF GUN W/SAFE SYSTEM. TIE - IN WITH GAMMA TO CORR. PERF DEPTH AT 10,700' TO 10,720', FIRE GUN. OBTAIN CCL LOGGING UP. POOH. 21:00 AT SURFACE, PERF GUN DID NOT FIRE, SUSPECT BAD GAMMA GUN TOOL. 21:30 RDFN, TRY AGAIN IN THE A.M. ARCO Alaska, Inc. ~-~ KUPARUK RIVER UNIT ~k, WELL SERVICE REPORT '~, K1 (1C-17(W4-6)) WELL JOB SCOPE JOB NUMBER 1 C-17 RIG WORKOVER, WORKOVER SUPPORT 1223981612.1 DATE DAILY WORK UNIT NUMBER 12/25/98 INITIAL PERFORATIONS DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 1 YES YES ALLDREDGE JOHNS FIELD AFC# CC# Signed ESTIMATE 999153 230DS 10CG Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann I Final Outer Ann 300 PSI 400 PSI 0 PSI 0 PSI 0 PSII 0 PSI DAILY SUMMARY PERFORATED 10,690' RKB TO 10,720 RKB WITH 2.50" HALLOW CARRIER GUNS, 4 SPF 180 DEGREE PHASING.[Perf] I TIME LOG ENTRY 07:00 MIRU SCHLUMBERGER E-LINE, SAFETY MEETING 07:45 PRESSURE TEST TO 3000 PSI. 08:00 RIH WITH CCL AND 20', 2.50 HALLOW CARRIER BH, 4SPF GUN. TIE -IN WITH COLLAR FROM JEWELRY LOG DATED 12-24-98. TOP SHOT AT 10,700' TO BTM AT 10,720'. POOH. 10:45 RIH WITH CCL, 10 ' HALLOW CARRIER 2.50", BH, 4SPF, TIE -IN, FIRED GUN WITH TOP SHOT AT 10,690' TO BTM ATO 10,700'. POOH. 13:20 AT SURFACE, GUN FIRED OK, RDMO. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,~ WELL SERVICE REPORT '~, K1(1C-17(W4-6)) WELL JOB SCOPE JOB NUMBER 1C-17 HPBD, HPBD SUPPORT 0106991413.2 DATE DAILY WORK UNIT NUMBER 01/07/99 'C' SAND HPBD. DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 1 YES YES DS-YOAKUM SMITH FIELD AFC# CC# Signed ESTIMATE 999153 230DS 10CG Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 1250 PSI 1250 PSI 7 PSI 0 PSII 210 PSII 210 PSI DAILY SUMMARY PUMPED 'C' SAND HPBD. PUMPED 4868# OF 20/40 SAND IN SCOUR STAGES. PUMPED 2940# ROCK SALT IN DIVERSION STAGES. USED A TOTAL OF 1766 BBLS OF SW. FP'D WELL W/30 BBLS OF DSL. AVG TREATING PRESSURE 3878 PSI. FORMATION BROKE DOWN F/8500 PSI DOWN TO 6250 PSI DURING INITIAL 300 BBL STAGE.[HPBD] TIME LOG ENTRY 05:30 MIRU HPBD EQUIPMENT. 08:45 SAFETY MTG, 14 PEOPLE ON LOCATION. 09:00 START PRIMING PUMPS, DEVELOPED LEAK ON THE MISSILE ON THE HP SIDE. S.D. VAC OUT SYSTEM TO MAKE REPAIRS. 10:00 START PRIMING PUMPS AGAIN. REPLACED O-RING ON HAMMER UNION END CAP. 10:15 PT SURFACE EQUIPMENT AND TREATING LINE TO 9750 PSI. 10:20 SET TREESAVER. OPENED BACKSIDE AND PRESSURED IT UP TO 3300 PSI. 10:30 PUMP STAGE 1 HPBD. 300 BBLS SLK. SW40 BPM, PRESSURE BROKE DOWN @ 8500 PSi AND WENT DOWN TO 6250 PSI. 10:40 PUMP 50 BBLS 1 PPA 20/40 SLK. SW @ 25 BPM. WHTP= 6490 > 6290 PSI. 10:42 PUMP 300 BBLS SLK. SW FLUSH @ 40 BPM, WHTP= 6400 > 6300 PSI. 10:49 SD AND OBTAIN ISIP=2022 PSI 11:01 PUMP DIVERSION/HPBD/SCOUR STAGE. 10 BBLS GD 2PPG ROCK SALT, 7 BPM. WHTP=2486 11:03 PUMP 10 BBL GD SPACER @ 7 BPM, WHTP= 2435 PSI 11:04 PUMP 5 BBL GD 2PPG ROCK SALT STAGE @ 7 BPM, WHTP= 2769 PSI 11:05 PUMP 5 BBL GD SPACER @ 7 BPM, WHTP= 2641 PSI 11:06 PUMP 150 BBL SLICK SW FLUSH @ 40 BPM, WHTP= 5269 PSI 11:11 PUMP 50 BBL 1 PPA 20/40 SLK SW SCOUR STAGE @ 40 BPM, WHTP= 5544 PSI 11:13 PUMP PUMP 400 BBL SLK SW CONDITIONING STAGE @ 40 BPM, WHTP= 5804 PSI 11:25 SHUT DOWN FOR ISIP= 2444 PSI 11:39 PUMP 10 BBL GD 2PPG ROCK SALT STAGE @ 7 BPM, WHTP= 2586 PSI TIME LOG ENTRY 11:40 PUMP 10 BBL GD SPACER @ 7 BPM, WHTP= 2710 PSI 11:41 PUMP 10 BBL GD 2PPG ROCK SALT STAGE @ 7 BPM, WHTP= 2875 PSI 11:43 PUMP 10 BBL SPACER @ 7 BPM, WHTP= 2884 PSI 11:44 PUMP 150 BBL SLK SW @ 20 BPM, WHTP= 5168 PSI 11:50 PUMP 340 BBL SLK SW @ 40 BPM, WHTP=4912 PSI 12:00 SHUTDOWN DUE TO SUCTION HOSE FAILURE ON #1 HIGH PRESSURE PUMP. SECURE WELL AND MISSILE SUCTION/DISCHARGE VALVES TO #1 PUMP. 12:22 PUMP 30 BBL DSL FREEZE PROTECT DOWN THE WELL. 12:23 SHUTDOWN AND SECURED EQUIPMENT AND STARTED RIGGING DOWN. Date: 1/11/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:lC-17 WELL ID: AK9157 TYPE: AFC: AK9157 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:il/15/98 START COMP: RIG:RIG % 245 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22872-00 11/13/98 (D1) TD: 121' (121) SUPV:DON E. BREEDEN 11/14/98 (D2) TD: 121'( 0) SUPV:DON E. BREEDEN 11/15/98 (D3) TD: 1623' (1502) SUPV:DON E. BREEDEN 11/16/98 (D4) TD: 4068' (2445) SUPV:DON E. BREEDEN 11/17/98 (D5) TD: 5568' (1500) SUPV:DON E. BREEDEN 11/18/98 (D6) TD: 7324'(1756) SUPV:DON E. BREEDEN MW: 0.0 VISC: MOVING RIG 0 PV/YP: 0/ 0 APIWL: 0.0 Move rig. MW: 0.0 VISC: DRILLING @ 146' 0 PV/YP: 0/ 0 APIWL: 0.0 Move rig to lC pad. Accept rig @ 1100 hrs. 11/14/98. NU diverter system and test. MW: 10.2 VlSC: 152 PV/YP: 30/50 DRILLING AT 2500' APIWL: 9.2 Spud at 121' and drill to 215' Circulate gravel out of hole. Replace impeller in #1 Disc-Flow pump & replace expansion sleeve. Drill to 1194'. Circulate out gas cut mud. Drill to 1623' MW: 10.6 VISC: 143 PV/YP: 42/60 DRILLING AT 5000' APIWL: 6.0 Drill from 1623' to 3317' Circulate out gas cut mud. Drill to 3411' Circulate out gas cut mud. Drill to 3599' Circulate out gas cut mud. Drill to 4068' MW: 10.5 VISC: 145 PV/YP: 45/60 DRILLING AT 5825' APIWL: 6.0 Drill from 4068' to 5568'. Pumped lo/hi visc sweeps. Lost 400 psi pump pressure. MWD stopped sending pulses. Circulate out first 5 stands. Pump slug. Started swabbing. Found choke nozzle in MWD pulser washed out. Change bit. RIH. MW: 10.7 VISC: 114 PV/YP: 42/50 START SHORT TRIP FROM 7606' MD APIWL: 4.4 Drill from 5568' to 7324' Circulate out gas cut mud. Date: 1/11/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 11/19/98 (D7) TD: 7606' (282) SUPV:DON E. BREEDEN 11/20/98 (D8) TD: 7606' ( 0) SUPV:DON E. BREEDEN 11/21/98 (D9) TD: 7606' ( 0) SUPV:DON E. BREEDEN 11/22/98 (D10) TD: 7606' ( 0) SUPV:DON E. BREEDEN 11/23/98 (Dll) TD: 7626' ( 20) SUPV:DON E. BREEDEN 11/24/98 (D12) TD: 8447'(821) SUPV:M.B.WINFREE 11/25/98 (D13) TD:10530' (2083) SUPV:G.R. WHITLOCK 11/26/98 (D14) TD:10540' ( 10) SUPV:G.R. WHITLOCK MW: 10.7 VISC: 149 PV/YP: 51/60 RUNNING 9-5/8" SURFACE CASING APIWL: 3.5 Drill from 7324' to 7606' MW: 10.4 VISC: 85 PV/YP: 28/28 PULLING SURFACE CASING APIWL: 6.0 Run 9-5/8" surface casing. Circulate casing, started with full returns and steadily lost returns. MW: 10.4 VISC: 93 PV/YP: 35/39 APIWL: 4.4 BREAK CIRCULATION & LAND HANGER, SHOE @ 7597' Work casing and try to regain full circulation, no go. Continue building and conditioning mud. Re-run 9-5/8" casing. Circulate casing volume. MW: 10.4 VISC: 70 PV/YP: 30/30 APIWL: 4.2 CBU @ 2566' - PREPARE TO DRILL OUT STAGE COLLAR. Run 9-5/8" casing. Pump first and second stage cement. MW: 8.5 VISC: 46 PV/YP: 9/14 APIWL: 12.4 PERFORMING FORMATION LEAK-OFF TEST %2: 14.1 PPG EMW LEAK-OF NU BOPE and test to 300/3500 psi. Drill out cement, plug & stage tool at 2592'. Drill 20' of new hole to 7626' MW: 8.9 VISC: 52 PV/YP: 15/20 DRILLING AHEAD APIWL: 6.0 Perform LOT, EMW=14.9 ppg. Drilled from 7626' to 7646' Performed LOT %2, EMW=14.1 ppg. Drilled from 7646' to 8447' RIH MW: 10.9 VISC: 63 PV/YP: 29/30 APIWL: 3.9 Drill from 8447' to 10530' Raised mud wt to 10.9 ppg while drilling from 10200' to 10530' MW: 9.8 VISC: 55 PV/YP: 19/19 APIWL: 4.2 RUNNING 7" CASING RIG ON HIGHLINE 24 HRS Circ. Flow check - slight flow. CBU w/no gas back to surface. Well breathing. Perform LOT to 11.7 ppg EMW. Break circ slowly w/partial returns. Lost all returns. CBU reducing mud wt to 9.8 ppg. Drill from 10530' to 10540' Date: 1/11/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 11/27/98 (D15) TD:10540' 0) SUPV:G.R. WHITLOCK 11/28/98 D16) TD:10540' 0) SUPV:G.R. WHITLOCK 11/29/98 D17) TD:10914' 374) SUPV:G.R. WHITLOCK 11/30/98 D18) TD:10969' 55) SUPV:G.R. WHITLOCK 12/01/98 D19) TD:10969' 0) SUPV:G.R. WHITLOCK 12/02/98 D20) TD:10969' 0) SUPV:G.R. WHITLOCK 12/03/98 (D21) TD:10969' ( 0) SUPV:G.R. WHITLOCK MW: 9.7 VISC: 52 PV/YP: 19/20 RIGGING UP TO TEST BOPE Run 7" casing to 10540'. Cement casing. MW: 10.9 rISC: 52 PV/YP: 77/33 APIWL: 2.4 CIRC FOR LOT RIG ON HIGHLINE 24 HRS N/U BOPE. Test BOPE to 300/5000 psi. Tag cement @ 10455' MW: 10.9 VISC: 82 PV/YP: 39/43 APIWL: 2.3 CIRCULATING BEFORE RUNNING LINER Drill float equipment, shoe jts. Drill from 10540' to 10560' Run FIT to 15.9 ppg EMW. Drill from 10560' to 10914' MW: 11.2 VISC: 82 PV/YP: 39/44 APIWL: 2.2 RUNNING LINER RIG ON HIGHLINE 24 HRS Drill from 10914' to 10969' CBU. Had gas cut mud to 9.0 ppg. Raise mud wt to 11.2 ppg. Run 4.5" liner. MW: 11.2 rISC: 62 PV/YP: 31/27 APIWL: 2.3 RUNNING 3-1/2" COMPLETION RIG ON HIGHLINE 24 HRS RIH w/4.5" liner. Pump cement. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED RIG ON HIGHLINE 24 HRS RIH w/ completion assembly. Freeze protect well. N/D BOPE. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED RIG ON HIGHLINE 8 HRS N/U master valve and test packoff to 5000 psi. Released rig at 0800 12/3/98. APIWL: 4.6 RIG ON HIGHLI North Slope Alaska ASP Zone 4 Kuparuk ~ C, Slot ~ C-~ 7 ~C-~7 Job No. AKMM9OOf6, Surveyed: 15 November, 1998 S UR VEY REPORT DEC 08 1998 Alaska OiI& Gas Con~. Co~mis~o~ 8 December, 1998 Your Ref: API-500292287200 KBE- 101.5' MWD Survey Instrument Surface Coordinates: 5968838.00 N, 561568.78 E (70° 19' 31.4542" N, 149° 30' 02.6650" W) sp~r~r',~-sum DRILLING SI~RVII--ES Survey Ref: svy113 Sperry-Sun Drilling Services Survey Report for 1C-17 Your Ref: API-500292287200 Job No. AKMMgO016, Surveyed: 15 November, 1998 North Slope Alaska Measured Depth (ft) Incl. Sub-Sea Depth (ft) 0.00 0.000 0.000 -101.50 121.00 0.000 0.000 19.50 196.68 0.660 244.570 95.18 287.10 3.720 230.080 185.52 379.70 8.400 238.130 277.58 469.74 10.600 251.430 560.53 10.760 264.710 651.46 11.580 281.040 742.28 14.580 293.280 832.89 17.850 303.080 366.39 455.62 544.85 633.32 720.33 922.38 18.980 310.720 805.25 1013.25 21.580 318,570 890.50 1105.03 27.190 322.040 974.06 1199.17 30.200 323.170 1056.63 1292.56 32.180 325.010 1136.52 1385.71 34.900 326.230 1214.15 1479.92 38.630 326.710 1289.61 1571.28 43.030 326.380 1358.72 1664.45 45.940 326,350 1425.18 1757.52 49.990 328.680 1487.49 1851.41 53,970 328.920 1545.31 1945.41 57.320 328.950 1598.35 2039.07 61.650 329.190 1645.90 2132.90 64.350 329,100 1688.49 2411.31 62.670 329.700 1812.67 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 0.00 0.00 N 121.00 0.00 N 196.68 0.19 S 287.O2 2.29 S 379.08 7.8O S 467.89 13.91S 557.12 17.35 S 646.35 16.38 S 734.82 10.12 S 821.83 1.98 N 906.75 18.96 N 992,00 41.14 N 1075.56 70.35 N 1158.13 106.27 N 1238.02 145.45 N 1315,65 187.93 N 1391.11 234.93 N 1460.22 284.75 N 1526.68 339.10 N 1588.99 397.41N 1646.81 460.67 N 1699.85 527.13 N 1747.40 596.33 N 1789.99 668.10 N 1914.17 882.56 N Dogleg Rate (°/100ft) Vertical Section (ft) 0.00 E 5968838.00 N 561568.78 E 0.00 0.00 E 5968838.00 N 561568.78 E 0.000 0.00 0.39W 5968837.81N 561568.39 E 0.872 0.04 3.11W 5968835.68 N 561565.68 E 3.412 -0.35 11.17W 5968830.11N 561557.68 E 5.124 -0.88 24.61W 5968823.89 N 561544.29 E 3.436 0.86 40.96W 5968820.32 N 561527.96 E 2.711 6.39 58.38W 5968821.14 N 561510.54 E 3.581 16.24 77.83W 5968827.25 N 561491.03 E 4.479 31.68 99.95W 5968839.16 N 561468.81E 4.694 53.48 122.48W 5968855.95 N 561446.15 E 2.975 79.68 144.75W 5968877.95 N 561423.70 E 4.136 110.19 168.83W 5968906.96 N 561399.37 E 6.306 147.65 196.26W 5968942.65 N 561371.65 E 3.249 192.59 224.61W 5968981.60 N 561342.99 E 2.353 240.78 253.65W 5969023.84 N 561313.60 E 3.008 292.16 264.78W 5969070.58 N 561282.08 E 3.971 348.50 317.71W 5969120.13 N 561248.74 E 4.822 408.17 353.87W 5969174.18 N 561212.14 E 3.123 473.39 390.94W 5969232.19 N 561174.59 E 4.732 542.48 429.25W 5969295.13 N 561135.76 E 4.244 616.43 469.29W 5969361.27 N 561095.18 E 3.564 694.02 510.75W 5969430.12 N 561053.16 E 4.628 774.69 553.62W 5969501.53 N 561009.70 E 2.879 858.28 680.47W 5969714.95 N 560881.09 E 0.634 1107.44 ASP Zone 4 Kuparuk 1C Comment Continued... 8 December, 1998 - 14:24 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for lC-17 Your Ref: API-500292287200 Job No. AKMMgO016, Surveyed: 15 November, 1998 North Slope Alaska Measured Depth (ft) 2689.60 2967.29 3247.33 3528.14 3811.40 4090.54 4373.38 4648.92 4927.67 5204.70 5394.75 5674.21 5954.50 6234.89 6510.16 6788.55 7068.76 7347.69 7532.35 7734.19 8014.71 8276.87 8481.83 8576.06 8669.77 Incl. 61.650 64.730 64,560 63.440 61.900 62.680 64.060 60.290 60.030 57.800 58,920 58.730 59.560 62.320 62.170 60,460 62,960 61.430 59.860 62.890 62.220 61,750 59.650 58.050 55.180 329.710 329.950 331.220 330.480 330.290 330.350 329.860 329.970 331.220 331.740 332.040 330.360 327.300 328,310 328.220 328.180 329.910 330.060 327.220 331.900 331.200 330.960 328.840 328.210 327,690 Sub-Sea Depth (ft) 1942.63 2067,86 2187.79 2310.89 2440.93 2570.73 2697.50 2826.09 2964.80 3107.82 3207.52 3352.19 3495.97 3632.15 3760.34 3893.96 4026.76 4156.86 4247.40 4344.13 4473.42 4596.55 4696.86 4745.60 4797.16 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 2044.13 1095.04 N 804.60W 5969926.40 N 560755.22 E 2169,36 1309.28 N 929.14W 5970139.61N 560628.93 E 2289.29 1529.71N 1053.42W 5970359.02 N 560502.84E 2412.39 1750.14 N 1176.35W 5970578.43 N 560378.11E 2542.43 1968.90 N 1300.70W 5970796.16 N 560251.97 E 2672.23 2183.60 N 1423.06W 5971009.85 N 560127.85 E 2799.00 2402.79 N 1549,08W 5971228.00 N 560000.04 E 2927.59 2613.60 N 1671.22W 5971437.80 N 559876.18 E 3066.30 2824.23 N 1789.93W 5971647.45 N 559755.74 E 3209.32 3032.67 N 1903.21W 5971854.96 N 559640.75 E 3309.02 3175.39 N 1979.44W 5971997.04 N 559563.35 E 3453.69 3384.91 N 2094.62W 5972205.61N 559446.45 E 3597.47 3590.74 N 2219.16W 5972410.41N 559320.23 E 3733.65 3798.13 N 2349.71W 5972616.73 N 559187.99 E 3861.84 4005.31N 2477.84W 5972822.85 N 559058.16 E 3995.46 4212.87 N 2606.53W 5973029.34 N 558927.77 E 4128.26 4424.46 N 2733.39W 5973239.89 N 558799.18 E 4258.36 4638.09 N 2856.81W 5973452.50 N 558674.01E 4348.90 4775.52 N 2940.53W 5973589.23 N 558589.17 E 4445.63 4928.24 N 3030.15W 5973741.21 N 558498.30 E 4574.92 5147.12 N 3148.74W 5973959.12 N 558377.91 E 4698.05 5349.70 N 3260,66W 5974160.77 N 558264.33 E 4798.36 5504.34 N 3350.26W 5974314.66 N 558173.47 E 4847.10 5573.11N 3392.36W 5974383.09 N 558130.81E 4898.66 5639.43 N 3433.87W 5974449.07 N 558088.75 E Dogleg Rate (°/'~OOft) 0.367 1.112 0.414 0.464 0.547 0.280 0.512 1.369 0.400 0.821 0.604 0.519 0.983 1.033 0.062 0.614 1.045 0.551 1.587 2.529 0.326 0.197 1.365 1.792 3.097 Vertical Section (ft) 1353.48 1601.25 1854.18 2106.40 2357.94 2604.98 2857.74 3101.33 3342.99 3579.97 3741.53 3980.41 4220.98 4466.01 4709.60 4953.80 5200.50 5447.17 5608.09 5785.15 6033.80 6265.06 6443.74 6524.38 6602.61 ASP Zone 4 Kuparuk 1C Comment Continued... 8 December, 1998 - 14:24 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for lC-17 Your Ref: API-500292287200 Job No. AKMMgO016, Surveyed: 15 November, 1998 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 8763.00 52.960 327.590 4851.87 8856.76 51.510 329.520 4909.29 8949.90 51.270 330.120 4967.41 9043.17 51.040 329.570 5025.91 9137.21 48.270 330.490 5086.79 9229.47 46.720 329.190 5149.12 9322.85 44.570 331.240 5214.40 9413.52 42.240 330.100 5280.27 9505.70 38.390 329.410 5350.55 9599.72 36.210 328.710 5425.33 9692.30 34.310 329.300 5500.93 9783.50 33.080 329.040 5576.80 9877.54 32.750 328.950 5655.75 9970.56 30.990 332.020 5734.75 10063.38 27.840 330.190 5815.59 10156.36 26.580 329.690 5898.28 10248.34 24.050 330.510 5981.42 10340.44 21.570 330.570 6066.31 10434.21 20.720 331.260 6153.77 10467.17 20.530 331.170 6184.62 10729.38 20,420 343.670 6430.38 10821.15 20.760 342.470 6516.29 10917.13 20.150 344.030 6606.22 10969.00 20.150 344.030 6654.91 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 4953.37 5703.19 N 3474.28W 5974512.50 N 558047.83 E 5010.79 5766.42 N 3512.95W 5974575.40 N 558008.64E 5068.91 5829.33 N 3549.54W 5974638.01N 557971.53 E 5127.41 5892.14 N 3586.03W 5974700.52 N 557934.53 E 5188,29 5954,22 N 3621.84W 5974762.30 N 557898.21E 5250.62 6013.03 N 3656.00W 5974820.83 N 557863.57 E 5315,90 6070.96 N 3689.18W 5974878.48 N 557829.91E 5381,77 6125.27 N 3719.69W 5974932,55 N 557798.96 E 5452.05 6176.79 N 3749.71W 5974983.82 N 557768.52 E 5526.83 6225.66 N 3778.99W 5975032.44 N 557738.83 E 5602.43 6271.47 N 3806.52W 5975078.03 N 557710.93 E 5678.30 6314.91 N 3832.45W 5975121.26 N 557684.65 E 5757.25 6358.71N 3858.77W 5975164.84N 557657.97 E 5836.25 6401.42 N 3882.98W 5975207.35 N 557633.40 E 5917.09 6441.34 N 3904.98W 5975247.09 N 557611.08 E 5999.78 5478.14 N 3926.27W 5975283.71N 557589.49 E 6082.92 6512.23 N 3945.88W 5975317.63 N 557569.60 E 6167.81 6543.31N 3963.44W 5975348.57 N 557551.78 E 6255.27 6572.87 N 3979.89W 5975377.99 N 557535.10 E 6286.12 6583.05 N 3985.48W 5975388.12 N 557529.42 E 6531.88 6667.26 N 4020.53W 5975472.05 N 557493.68 E 6617.79 6698.14 N 4029.93W 5975502.84N 557484.03 E 6707.72 6730.25 N 4039.60W 5975534.88 N 557474.09 E 6756.41 6747.43 N 4044.52W 5975552.02 N 557469.04 E Dogleg Rate (°/100ft) 2.383 2.245 0.565 0.521 3.038 1.975 2.786 2.711 4.205 2.362 2.085 1.358 0.355 2.572 3.529 1.377 2.777 2.693 0.945 0.584 1.665 0.591 0.852 0.000 Vertical Section (ft) 6678.08 6752.19 6824.96 6897.59 6969.24 7037.24 7103.98 7166.24 7225.86 7282.83 7336.27 7386.86 7437.96 7487.04 7532.58 7575.08 7614.40 7650.09 7683.89 7695.49 7785.68 7816.95 7849.43 7866.67 ASP Zone 4 Kuparuk lC Comment Projected Survey Continued.** 8 December, 1998 - 14:24 - 4 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1 C-17 Your Ref: API-500292287200 Job No. AKMM900'16, Surveyed: '15 November, 1998 North Slope Alaska ASP Zone 4 Kuparuk 1C All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. .:.,Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 27.362° (18-Nov-98) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 328.790° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10969.00ft., The Bottom Hole Displacement is 7866.76ft., in the Direction of 329.061 ° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (~t) (~t) (~t) (~t) 0.00 0.00 0.00 N 0.00 E Tie-on Survey 10969.00 6756.41 6747.43 N 4044.52 W Projected Survey 8 December, 1998 - 14:24 - 5 - DrillQuest STATE OF ALASKA ALASK...~AL AND GAS CONSERVATION COMMIt _. iON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend -- __ Alter casing Repair well Change appFeved program__ -- Pull tubing_ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1395' FNL, 563' FWL, Sec. 12, T11N, R10E, UM At top of productive interval 36' FNL, 1821' FWL, Sec. 2, T11N, R10E, UM At effective depth At total depth 55' FSL, 1768' FWL, Sec. 35, T12N, R10E, UM Operation Shutdown Plugging __ Re-enter suspended well Ti-me extension Stimulate - Variance__ P~-rforate__ -- Other X Annular Injection 6. Datum elevation (DF or KB) 41' RKB feet 5. Type of Well: Development -- Exploratory -- Stratigraphic __ Service X 7. Unit or Property name Kuparuk River Unit 8. Well number lC-17 9. Permit number 98-224 10. APl number 50-029-22872 11. Field/Pool Kuparuk River 12. Present well condition summary Total Depth: measured 10969 feet (approx) true vertical 6757 feet Effective depth: measured 10455 feet (approx) true vertical 6300' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 7556' 9.625" 1 O499' 7" 657' 4.5" measured N/A Plugs (measured) None Junk (measured) Cemented Measured depth 9 cubic yards 121' 930 sx AS III LW & 7597' 670 sx Class G & 60 sx AS I 175 sx Class G 10540' 112 sx Class G 10969' True vertical depth 121' 4381' 6354' 6757' true vertical N/A Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 10342' Packers and SSSV (type and measured depth) Baker ZXP Liner Pkr @ 10312' MD 0R GtNAL 13. Attachments Description summary of proposal Detailed operation program Contact Chip Alvord at 265-6120 with any questions. LO-T~est, surface cement details and casing de~'~rsheets __X BOP sketch 14. Estimated date for commencing operation December 1998 16. If proposal was verbally approved 15. Status of well classification as: Oil Gas Suspended Name of approver Date approved Service X 17. I hereby certify that the foregoing ~s true//and correct to the best of my knowledge. /~ga~ ~am~ O'~- Title Kuparuk Team Leader Signed 'L. Alvord 6120 FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical In'~grity Test_ Subseque~-form require 10- ...)~IG~NAL SIGNED BY Approved by the order of the Commission Robert N. Christer~son Commissioner IApprov~.,g;~ ~ ~ ~, Form 10-403 Rev 06/15/88 SUBMIT IN TRIPJ,.I,~;ATE . OO¥ ~ CASING / TUBING / LINER DETAIL ~-5/8" Surface Casing ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL: 1C-17 KRU DATE: 11/22/98 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS 65 Jts Joint 'B' Joint 'A' 127 Jts 1 Jt 2 Jts RKB to Landing Ring - Parker Rig #245 FMC Gen 4 Fluted Mandrel Casing Hanger & pup 9-5/8", 40#, L-80, BTC Casing (Joints #131 -#195~) 9-5/8", 40#, L-80, BTC Casing - Baker Locked Gemoco '754' Stage Cementin~l Tool 9-5/8", 40#, L-80, BTC Casing - Baker Locked 9-5/8", 40#, L-80, BTC Casing (~Joints #4- #130~) Gemoco Insert Shut-Off Baffle 9-5/8", 40#, L-80, BTC Casing Gemoco Float Collar ~Joint #3~ 9-5/8", 40#, L-80, BTC Casing Gemoco Float Shoe (Joints #1 & #2~ 40.35 2:26 40.35 2507.85 41.70 42.61 2550.46 2.76 2592.16 38.96 2594.92 4844.91 37.26 1.45 77.60 1.70 2633.88 7478.79 7478.79 7516.05 7517.50 7595.10 Bottom of Shoe ==>> 7596.80 I TD of 12-1/4" Hole = 7606" MD (~ 10' of Rathole) I Baker Lok thru Insert Shut-Off Baffle, plus Stage Collar to Joints 'A ' & 'B' Instafl Insert Shut-Off Baffle in Connection on Top of Joint #3 Run Sta~le Collar & Baker Lok'd Jts 'A' & 'B' on Top of Joint #130 Run FMC Han~ter on Top of Joint # 195 43 Bow SDrina Centralizers: I / Jt on first 15 joints, first 2 on stop rin~l in middle of joint; Then 1'every 3rd joint on Joints #18, 21, 24, 27, 30, 33, 36, 39, 42, ~5, 48, 51, 54, 57, #60, 63, 66, 69, 72, 75, 78, 81, 84, 87, 90, 93, 96, & 99, 2 Riaid Straiaht Blade Centralizers: Sfide I on Jt 'A' & Jt 'B' Leave OUT 10 ioints: #196 thru #205 Remarks: String Weights with Blocks: 310K# Up, 130K# Dn, 75K# Blocks. Ran 197 joints of casing. Drifted casing with 8.679" plastic rabbit. Used Arctic Grade APl Modified No Lead thread compou on all connections. Torqued connections to the base of the triangle stamp. Parker Rig #245 Drillin~l Supervisor: Don E. Breeden ARCO Alaska, Inc. Cementing Details Well Name: 1C-17 Report Date: 11122/98 Report Number: 10 Rig Name: RIG # 245 AFC No.: AK9157 Field: Kuparuk River Unit Casing Size Hole Diameter: Angle thru KRU: [ Shoe Depth: I LC Depth: % washout: 9-5/8" 12-1/4" 62* slantI 7597' MD 14381' TVDI 7479' MD Centralizers State type used, intervals covered and spacing Comments: 43 Gemoco Bow Springs: One on each of first 15 joints, first two on stop ring in middle of j°int; Then one every third joint thru joint #99. 2 ROTCO Rigid Sraight Blade Centralizers: On middle of joint on each side of Stage Collar at 2592' MD. Mud Weight: PV(prior cond}: PV(after cond): YP(prior cond): YP(after cond): Comments: 10.4 ppg 38 30 43 30 Visc: 98 sec to 70 sec Gels before: Gels after: Total Volume Circulated: 15/33 11/35 1743 Bbls Wash 0 Type: Volume: Weight: Comments: ARCO Wash 20 Bbls 8.34 ppg 1st Stage Spacer 0 Type: Volume: Weight: Comments: ARCO 40 Bbls 130 Bbls water 10.5 ppg / 8.34 ppg !1st Stage I 2nd Stage Lead Cement 0 Type: Mix wtr temp: No. of Sacks: I Weight: Yield: Comments: AS III LW 75' F 330 sx 1600 sxI 10.7 ppg 4.44 cfs 1st Stage / 2nd Stage Additives: Class G + 9% D44 + 0.6% D46 + 30% D53 + 1.5% D79 + 50% D124 + 1.5% Sl TallCement 0 Type: I Mixwtrtemp: No. ofSacks: I Weight: I Yield: Comments: Class G/AS I 75' F 670 sx 160 sx 15.8 ppg I 15.7 ppg 1.i7 cfs I 0.93 cfs =1st Stage 12nd Stage Additives: Class G + 1.0% S1 + 0.2% D46 + 0.3% D65 II Arctic Set I Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Sir. Wt. Up: Comments: 8.3 BPM 17.2 BPM 7.8 BPM 17.2 BPM 310K# (75K# Blocks) 1st Stage 12nd Stage Reciprocation length: Reciprocation speed: Str. Wt. Down: -15' -20 fpm 130K# (75K# Blocks) Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 567 Bbls I 196 Bbls 568 Bbls / 197 Bbls 147K# Calculated top of cement ' CP: Bumped plug: I Floats held: Cemented to Surface Date:11122/98 Yes I YesI Yes/Yes Time:13:30 / 17:30 Remarks: Circulated to condition hole & mud for cementing. Circulated 1743 Bbls, 8.5 BPM final rate, 600 psi. Reduced funnel viscosity from -100 sec to -70 sec, MW from 10.5+ ppg to 10.4 ppg. Reciprocated casing while circulating, 310K#. 335K# Up, 135K# Down. 1st Stage Cement Job: Dowell flush lines with 5 Bbls water. Test lines to 3500 psi. Pump 20 Bbls ARCO Wash, 5.5 BPM, 300 psi. Pump 40 Bbls, 10.5 ppg ARCO Spacer, 5.5 BPM, 350 psi. Mix & pump 263 Bbls, 330 sx, 10.7 ppg AS III LW Lead Cement, 7.1 BPM, 300 psi. Load & drop bypass plug. Mix & pump 129 Bbls, 15.8 ppg Class G Tail Cement, 7.0 BPM, 300 psi. Load & drop shut-off plug. Chase plug with 6 Bbls Tail Cement (670 sx total Tail). Follow with 24 Bbls wash-up water. Switch to rig pump & finish displacement with 538 Bbls mud, 8.3 BPM to 7.8 BPM, 300 psi to 1400 psi. Slowed rate to 4.6 BPM, 1250 psi to bump plug. Bumped plug & pressured up to 1550 psi. Bled off & checked floats, OK. Reciprocated casing until 10 Bbls before spacers reached shoe, pipe getting sticky about 5' up, pulling a liltle more each time to pull through next 5', up to 380K#; also losing more weight down. Tried once more up to 400K#, then set down on hanger & left set. Had full returns throughout, 1st Stage ClP (~ 1330 hrs, 11122/98. Pressured up & opened stage tool at 2592' MD, 1998' TVD. Stage tool opened at 2850 psi. Circulated hole clean through stage tool & reconditioned mud for 2nd stage cementing. Circulated 626 Bbls total, 8.1 BPM final rate, 375 psi. Circulated out 60 Bbls of spacers & about 160 Bbls of Lead Cement & cement contaminated mud. 2nd Stage Cement Job: Dowell prime up & pump 5 Bbls water, test lines, pump 25 Bbls more water. Mix & pump 459 Bbls, 600 sx, 10.7 ppg AS III LW Lead Cement, 7.1 BPM, 300 psi. Saw water flush, then cement contaminated mud at 430 Bbls pumped. Had 10.7+ ppg Lead Cement returns at 444 Bbls pumped. Switched to Tail at 459 Bbls Lead Cement pumped. Mix & pump 10 Bbls, 60 sx, 15.7 ppg Arctic Set I Tail Cement, 2.8 BPM, 250 psi. Drop closing plug & chase with 20 Bbls wash-up water, 6.8 BPM, 300 psi. Switch to rig pump & finish displacement with 177 Bbls mud, 7.2 BPM, 550 psi. Slowed to 5.3 BPM, 450 psi to bump plug. Bumped plug. Pressured up & saw stage tool close at 1200 psi. Pressured up to 2200 psi & held 5 minutes, OK. Bled off & checked floats, OK. Had good 10.7 ppg to 11.0 ppg Lead Cement returns to surface (approx. 220 Bbls). Had full returns throughout. 2nd Stage ClP {~ 1730 hfs, 11122/98. Cement Company: I Rig Contractor: Approved By: Dowell IParker Don E. Breeden CASING TEST and FORMATION INTEGRITY TEST Well Name: Supervisor: lC-17 Don E. Breeden/M.B. Winfree Date: 11/24/98 Casing Size and Description: 9 5/8", 40.0 ppf, L-80, BMTC Casing Setting Depth: 7,597' TMD 4,381' TVD Mud Weight: Hole Depth: LOT = 8.5 ppg EMW = Leak-off Press. + MW 0.052 x TVD 7,626' TMD 4,396' TVD 1,473 psi + 8.5 ppg EMW (0.052 x 4,381 ') = 15.0 ppg Fluid Pumped = 5.0 bbl Pump output = 0.1000 bps _..ITIME LINE : 3,300 psiJill i ill i i / I i i i [ i Jill [ i il i i il [ ill ill i i i i~-~j~.,~jTJ- ~NE ~: ~uiE ii'KS I 3,~ oo ~s~ ................. .... '~ ..... "- '- "_ _ ~ ~.~': " -:'-h'~- ", ~ -!- '.'. ~--'r _.,, ~,..'"" _~. ~. ,,. :!._,.,. ...... ~ .... "_:_",' :.'_:.v '_:_'_:.' .... _ ~:~°~lJ.__ ::: ::,-: _z- :_ _: _ _ -_--_..-..m.-~'':'''' '-"'-" _~_~_-'-: - 2,400 psi .... 2,300 psi .... 2,200 psi ............. 2,100 psi ...... 2,000 psi ........... ~:~ 1,900 psi ............... 1,800 psi ..... 1,700 psi ...... 1,~O0 psi 1,$00 psi I ,OUU psi -- 1,200 psil~~~l:--I:l--IzI.--.J "'-LEAK-OFF TEST uoo psi t~H-F%J-t-F-I-F-H-H i~iCASiNG TEST I I-I-t'-F-I 1.ooo ps~ t~~..,>..... LOT SHUT IN TIME I I--I-I-H 900 psi ~oo~s, J~r_L:l_-:l --,~ CASING TEST SHUT IN TIME IZIZZ[-I 7oo~si t~::~!~J~-½~ ; TIME LINE 600 psi ..................... · 0 psi st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st 0 2 4 6 8 0 6 8 k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k st st st st st st st st st st st st st kkkkkkkkkkkkk STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above ~..~.~ ~___~_~, IPr'~"/ "; "×""~"/' ,c~,~ ~ " 'i~'4' ,~,,5 ..... LEAK-OFF DATA MINUTES FOR FIT STROKES PRESSURE ..................... i ..... --4--s-!k--s- ..... l .... !9-?-?-.s--i----~ j 8stks ~ 291 psi ," ..................... j .... J~..s._t.k__s_ .... 1_____5._e.9.._p.s..i..__j i 24stks i 820 psi [ .................... i .... -i-g~-~ .... T .... ~'~,-~--I~%i----! j 32stks ,: 1,082psi ] : 36stks i 1,209psi j i 40stks i 1,332psi i .................... I ........................................ " ~ 44stks J 1,435psi J .................... 1 .... 'a-~'~ .... T-"i;~a-H~r--I .................... · ,' .................... ~ ................... -i i i i I I .................... ~ .................... + ................... I I SHUT IN TIME i SHUT IN PRESSURE ..... '6:'6'-fi;iF~- .... i .................... -,,' .... i;'~'6'65~[ .... .................... "l .................... 4- .................... ..... .!_-.o....m. Ln. .... J .................... L_!,~Z.°..P.?.L.. .... -3-:-°----m-Ln- .... i .................... L-],-2--°-EP-?!-- 5.0min j ~ 1,075psi , 9.0 min j i 919 psi .................... 'l .................... ~l. .................... .... j_5_:_0____m_[.n..._! .................... L._.8..4..o...Rs_j_ .... .... .2_.o_...o____m.[.n.__.j .................... ,', _ _.7..~..0_. _p.s..i_ ..... 25.0 min ! i 730 psi .- ................... 4 .................... 4- .................... .... .3_0___0____m_[.n____j .................... ,,' _____7_.0..0_ _Rs__i- .... NOTE: TO CLEAR DATA, HIGHLIGHT AND CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ............................ _O._s..tk..s. ............. _o__p__sj ....... ........................... !~.Lk.~ ........... ]._~_.~.~j ..... 8 stks 250 psi ~. .................... ~ .................... ~ .................... ..~ ..................... ,,, .... .!.2...s..t_k._s_ ......... ._4.s_9.?.?j. .... ..................... l .... .!_6.__s._tk.~ ......... ..~.9.9_P_.sJ ..... ..................... i .... ~.0_.~.~ ......... ._8._o..o_p_.?.i_ .... , ] 24stks . 950 psi .. .................... ~ .... .E.8_?..t.k.?_ ........ !,J__o_.o_R.s_L_... ~ ] 32stks . 1,275psi , 36 stks 1,450 psi .................... · ~ .................... '1 ..................... ..................... i .... .4_ .O_ .s. !_k_ .s_ .... j___]:_6_~.5_.R.s.L_. ..................... ! .... _4_.4_s. Lk_.s_ ........ ]:_8_Es_..P..S.!..~ ..................... i .... -4--8--!-t-k-! ........ ..................... i .... §~..s_.t.k..s. ........ !,!!!_.P_!L ..................... i .... §.6._.s_t.k..s. ........ !,.4..o.9__.p_!L. ..................... i .... .6..O._!!.k..s. ........ !,§!.5__.P__S_L . ] 68stks . 3,025 psi .. ,t I SHUT IN TIME i ..... .°---°----m-Ln- .... i ........................ .3_:.°..2_.5._.P_.S_L.. ..... .!-.°__._m_i._n_ .... i ........................ .3_,.0_.2._s__R_s_L 2.0 min i 3,025 psi ..... ~..o__._m_i..n_ .... i ........................ ..... .4_-.o._mL._ ......................... , .... .5._.O._._m_L_n- ............................................. . j 3,025 psi 6.0 min i 3,025 psi ..... Z-.O....m.Ln. ......................... j___~,.°_~ER?_L_~ ..... .8_-.o._..mL2 .......................... L_~,.o.~E.p..~.L_.~ , .... .9.:_0._..m.[_n_ .............................................. . i 3,025psi l .... !o_-.o__.m.L~_ ......................... L_.~.,.o.~.R?.L..~ 15.0 _mi_n. ............................................. ................ i 3,025psi ! .... _2_.0_..0_..m..i..n. ........................ j___.3. ,.0..2_5_.R .s!._ ] .... _2..5_-.o__.m..Ln. ........................ j__.9=_°..2._EE~.L.j .... _3_0_ _.0_ _ .m_ _ i. _n_ ........................ ]___~,.O3_~_R~L] PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: Supervisor: 1C-17 G.R. Whitlock 9 5/8", 40.0 ppf, L-80, BMTC Date: 11/26/98 Casing Size and Description: Casing Setting Depth: <:)7~tt 7,597' TMD 4,381' TVD Mud Weight: Hole Depth: 10.9 ppg 6,344' TVD 254 psi LOT = (0.052 x 4,381') EMW = Leak-off Press. + MW 0.052 x TVD 10530' TMD ./ O-,~-g 0.5:-7 ~"..<~ + 10.9 ppg = 11.7 ppg EMW @ 9-5/8" Csg Shoe Fluid Pumped = 3.4 bbl Pump output = 0.1000 bps ~.~TIME LINEE 3.a~OO psi .... ©NE Mi~UTE:TiCK$ - -_---::: --: ...... .---- __: .... - .... :_:--:: ._-._:-----_ .::: .... ~:~I ................................ 2',600psi--~--------- 7_- i~_ZZ~ _L'~ -__L~ ....................... 2,500 psi 2,400 psi ............................ 2,300 psi 2.200 psi ......................... 2,100 psi ........................... 2,000 psi 1,900 psi ............................... 1,800 psi ....................... 1.700 psi 1,600 psi .................... 1,500 psi ...... 1,400 ps[ '~hoo ~sl(2°° si t-~.--~t~_Ej~f_--~--~k~t~~~ ~-~l~ =bASINGLEAK-OFFTEsTTEST 'i,9oo psi t~t-h-i-1--t-ll ........ i:,.,.. LOT SHUT IN TIME I v2.o p,! ,__,--,--,---,-,-,--,, _.,.?_ C:AS~NO TEST SHUT IN T~ME I-1WI-] ~uu pm t~-d--I--t--l--l~l~l~l--h-II , ¥ -- 700psi I-~L3-~d---I-H---FII ~ TIMELINE - ...... ,500 psi 400 psi ......................... 300 psi ......................... 200 psi ....................... 0 psi 2 468~121416182~222426283~32~436384~424446485~254~586~6264~6687~727476788~828486889g929496981~1~1~1~1~11 st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st 0 2 4 6 8 0 k k kkkk k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k kstststststst k k k k k k STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR FIT STROKES PRESSURE ........................... g___s_t_k_.s_ ........... _o__p.._sj ....... 2 stks 45 psi ........................... _4___s__t_k_.s_ .......... !.2.9_..p9..i_ .... 6 stks 160 psi ........................... _l}_s_!lE.s_ .......... .1.?_9_..Rs.J. .... 10 stks 203 psi 12 stks 214 psi ........................ J.4_.~.t.k.~ ......... ._~__EO___R?.~ .... .......................... J.6_.~.t.k.?. ........ .g.g..~___P.*_.L .... 18 stks 232 psi 20 stks 235 psi · 22stks 236 psi .......................... 3.6__.s__t.k_.s_ ........ Z_4._s_._P.S.Z .... .......................... 3A.*_.t~.*_ ......... .2..4Z..Rs_/ .... CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE 0 stks ! 0 Esi 4stks i 125 psi ~. ....................~ .................... .... .................... .., ........................... .8._.s__t.k_.s_ ..... j .... ..2..5.9._p_s_.i ..... 12stks i 450 psi r .................... ~' .................... -t .................... 16stks i 600 psi .......................... g4__~!~.,_ .... j .... .~..s..O..E?j ..... .......................... ~§_?_!~?_ .... i_ J__,!.o._o__R_s_L__ .......................... ~&.s_.t.k._s. .... j.._j,]Z.s_.R.s.!_.. 36stks i 1,450psi .......................... .4_o. _.s__t.k__s_ .... 44stks j 1,825psi " .................... '& .................... 1 ..................... .......................... ?_A.Et¥. .... L...2.,.o_2..E.R.~.L. .......................... .s_&~.t.k._s. .... j._ ] ,.2_2_s_.p.?.L .......................... .s_~_~!~ .... i...~,.4..o._o_._R.s.L., 30stks 248 psi . 60stks i 2,625 psi i .................... 1 .... .... T .... .... i ..................... J' .................... I .................... T' .................... J t .................... ~ .................... I ..................... i .................... ~ .................... ~- .................... i i .................... i .................... i [ SHUT IN TIME i ~ .................... .i .................... .i- .................... i .'- .................... ~ .................... -~ ..................... i 0.0 min ! ! r .... '~':6'F~f~' .... i .................... i .................... i l SHUTIN TIME i SHUTIN PRESSURE [ .... -~]~5-~[~1- .... [ ] .... .... .................... .... , ..... [ T.¥-r~f~' i .... .... .................... l Yg'i"l~'i'i' l .... .... i 5.0min i [ -i55-'r~i~- ] .... .... .................... ,~ .... ¥i-i--~-iT---i r EE-~[~- i .... .... .................... i .................... i ~ ....................~ .................... ~ .................... ~ ~ .................... { .................... 4 ....................-I i 3.0min i i 144 psi [ ; 7.0min [ .... -ZB"~[~' .... i .................... T .... :m'i'b"m;iT .... i r .... 'EB'~[Ff .... ! .................... i .................... i ! 5.0min i [ 135 psi ! i 9.0min l i ..... E'6"fiii~- .... i .................... T .... ¥i'i'-~-i'i' .... i F'"fEiE'iii"-'i .................... i .................... i 7.0min 130 psi i 15.0min i 9.0 min 125 psi i .... '~i~5'~[~'"'f .................... ..................... ~ .................... -.- .................... , .- ................... -t .................... 4 .................... -, .... j.o.:.o_.m.L~- ............................. ]..2..4_p.~_j_ .... [ ....9_o.:.o_..m.i..n....] .................... j .................... j NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Daily Drilling Report ARCO Alaska, Inc. AFC No. Date Rpt No Rig Accept - hrs Days Since Accept/Est: 8.54 / 5.25 AK9157 11/22/98 10 11/14/98 11:00:00 Rig Relase - hrs: AM Well: 1C-17 Depth (MD/TVD) 7606/4386 Prev Depth MD: 7606 Progress: 0 Contractor: Parker Daily Cost $ 359375 Cum Cost $1163212 Est Cost To Date $ 775000 Rig Name: RIG # 245 Last Csg: 9-5/8" @ 7597' Next Csg: 7" @ 10,503' Shoe Test: Operation At 0600: CBU @ 2566' - Prepare to drill out stage collar. Upcoming Operations: Drill 8-1/2" intermediate hole MUD DATA DRILLING DATA BIT DATA ' EH&S DRILLS/BOP DATA :: MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST Bop/DIVERT LAST BOP/DRILL LSN D N TST 11/18/98 11/14/98 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 10.4ppg 10/27/98 11/16/98 VISCOSITY PU WT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 70sqc N SPACE 11/09/98 11/10/98 PV/YP SO WT TYPE TYPE TYPE FUEL & WATER 30 / 30 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 4040 11/35/ APl WL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 2000 4.2 11/22/98 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 100 mi/30 min INjEcTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER& 11.0% I C-13 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMp °F 9 577bb, III / / lC-17 MBT PUMP NO WOE 2 WOE 2 RATE (bpm) WIND SPEED 7 20.0 112131 4 ph LINER SZ RPM I RPM 1 PRESSURE (psi) WIND DIRECTION 45° 7.6 615.515.51 14oo LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR °F -2.01 6.4% III Water Base Muds 1980 PIT VOL GPM 2 JETS JETS Cement ARCO PERSONNEL 1 233 III II111 IIIII 200 Other 600 DAILY MUD SPS 1 BIT COST BIT COST Fresh Water CONTRACTOR 30 $5356 III ~3o PERSONNEL Diesel 4O TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $102184 III III 11[ 2950 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 6 BARO~D III III Il 10690 PERSONNEL TOTAL 42 TIME I END HOURS I OPS CODE I HOLE SECT I PHASE OPS I OPERATIONS FROM 0000 - 0000 12:00 AM 06:00 AM 6.00 CASG SURF Casing and Run 9-5/8" surface casing. Circulate every joint down & Cementing circulate casing volume at 6593' & 7054'. MU fluted mandrel casing hanger & landing joint. Circulate down & land hanger with shoe at 7597'. 06:00 AM 10:30 AM 4.50 ClRC SURF Casing and Circulate to condition mud & hole for cementing. Cementing Circulated 1743 Bbls, 8.5 BPM final rate, 600 psi. Reduced visc from -100 sec to 70 sec, MW from 10.5+ ppg to 10.4 ppg. Reciprocated casing, 310K# - 335K# Up, 135K# Down. 10:30 AM 01:30 PM 3.00 CMT_CSG SURF Casing and 1st Stage Cement Job: Dowell flush lines with 5 Bbls water Cementing & test to 3500 psi. Pump 20 Bbls ARCO wash & 40 Bbis ~EC~t V~DI°'5ppgARcOspacer' Mix&pump263Bbls'330sx'1°'7 ppg AS Ill LW Lead Cement. Load & drop bypass plug. Mix & pump 129 Bbls, 15.8 ppg Class G Tail Cement. Load & drop shut-off plug & chase with 6 Bbls Tail Cement (670 sx total Tail). Displace with 24 Bbls wash up water. Switch to DEC 30 1998 rig pump & displace with 538 Bbls mud. Bumped plug. Floats held. Full returns. 1st Stage CIP @ 1330 hrs. Daily Drilling Report: 1C-17 11/22/98 Page I 01:30 PM 03:30 PM 2.00 CIRC 03:30 PM 06:00 PM 2.50 CMT_CSG 06:00 PM 07:00 PM 1.00 CMT_CSG 07:00 PM 09:00 PM 2.00 NU_ND 09:00 PM 09:30 PM 0.50 NU_ND 09:30 PM 10:00 PM 0.50 PREP 10:00 PM 12:00 AM 2.00 NU_ND 24.00 SURF SURF SURF SURF PROD PROD PROD Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Other Other Other Pressure up & open stage tool at 2592', tool sheared open at 2850 psi. Circulate hole clean through stage tool & recondition mud for 2nd stage cementing. Circulated 626 Bbls total. Circulated out 60 Bbls spacers & about 160 Bbls of Lead Cement & cement contaminated mud. 2nd Stage Cement Job: Dowell prime up & pump 5 Bbls water, test lines, pump 25 Bbls more water. Mix & pump 459 Bbls, 600 sx, 10.7 ppg AS III LW Lead Cement. Saw water flush, then cement contaminated mud at 430 Bbls pumped. Had 10.7+ ppg cement returns at 444 Bbls pumped. Switched to tail at 459 Bbls Lead Cement pumped. Mix & pump 10 Bbls, 60 sx, 15.7 ppg AS I Tail Cement. Drop closing plug & chase with 20 Bbls wash-up water. Switch to rig pump & displace with 177 Bbls mud. Bumped plug. Pressured up & saw stage tool close at 1200 psi. Pressured up to 2200 psi & held 5 minutes, OK. Floats held, 2nd Stage ClP @ 1730 hrs. Full returns. Had good 10.7 ppg to 11.0 ppg cement returns to surface (approx. 220 Bbls). Wash down riser & flowline. RD cement head & casing tools. LD landing joint. RU DP tools. Wash down surface equipment, bag, & knife valve. ND diverter system. MU FMC casing head & torque to 25K ft-lb. Cut off 133' of drilling line, NU 11" 3000 psi x 13-5/8" 5000 psi DSA & DOPE. Supervisor. DON E. BREEDEN Daily Drilling Report: 1 C-17 11/22/98 Page 2 Daily Drilling Report ARCO Alaska, Inc. AFC No. Date Rpt No Rig Accept - hrs Days Since Accept/Est: 9.54 / 6.5 AK9157 11/23/98 11AM11/14/98 11:00:00 Rig Relase - hrs: Well: 10-17 Depth (MD/TVD) 7626/4396 Prev Depth MD: 7606 Progress: 20 Contractor: Parker Daily Cost $ 88004 Cum Cost $1251216 Est Cost To Date $ 875000 Rig Name: RIG # 245 Last Csg: 9-5/8" @ 7597' Next Csg: 7" @ 10,503' Shoe Test: 14.1 ppg EMW Operation At 0600: Performing Formation Leak-Off Test #2:14.1 ppg EMW Leak-Off Upcoming Operations: Trip for BHA, Drill 8-1/2" hole MUD DATA DRILLING DATA BIT DATA EH&S : DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL LSN D 7626 3RR N TST 11/18/98 11/23/98 WEIGHT ROT WT SIZE SIZE EMPLOYER !LAST H2S DRILL LAST FIRE DRILL 8.5ppg 160 8-1/2" ~10/27/98 11/16/98 VISCOSITY PU WT VlAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 46sqc 275 STC N SPACE 11/09/98 11/10/98 PV/YP SO WT TYPE TYPE TYPE FUEL & WATER . 9 / 14 115 FDSS+2CR GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 6611 8 / 9 / LS8740 APl WL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 2500 12.4 11/23/98 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 100 ml/30 min 18 7388 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 1.5% 20 238 1 C-13 PERSONNEL :DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP °F 5 52Obb. III / / lO-17 MBT PUMP NO WOB 2 WOB 2 RATE (bpm) WIND SPEED 10 8.0 112131 3 )h LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 360° 10.0 615.515.51 1400 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR °F -14.78 '5.0% III Open Water Base Muds 1455 PiT VOL GPM 2 JETS JETS Fresh Water ARCO PERSONNEL 1 175 III IIIII IIIII 20o Diesel 100 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 30 s881o III RE o PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MlSC PERSONNEL 5 $110994 III III III 1755 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 6 BARO~D III III III 12445 PERSONNEL TOTAL 42 TIME J END HOURS J OPS CODE J HOLE SECT J PHASE OPS J OPERATIONS FROM 0000- 0000 12:00 AM 12:30 AM 0.50 NU_ND PROD Other NU BOPE. 12:30 AM 02:30 AM 2.00 BOPE PROD Other Test BOPE to 300 psi & 3500 psi, Annular to 300 psi & 3000 psi. Test accumulator. Test witnessed by Larry Wade, AOGCC Field Inspector. 02:30 AM 03:00 AM 0.50 PREP PROD Other Set wear bushing. 03:00 AM 04:30 AM 1.50 BHA PROD Other PU BHA #3. 04:30 AM 06:00 AM 1.50 TRIP_IN PROD Other RIH PU DP to 2566'. Tag stringers. 06:00 AM 09:30 AM 3.50 CLN_OUT PROD Other CBU. Test casing to 2000 psi for 10 minutes, OK. Drill out cement, plug, & stage tool at 2592'. CBU. Retest casing to 2000 psi for 10 minutes, OK. 09:30 AM 12:00 PM 2.50 TRIP_IN PROD Other RIH PU DP, 33 stands total. RIH to 5210'. Fill pipe. 12:00 PM 12:30 PM 0.50 RIGS PROD Other Service rig & top drive. 12:30 PM 01:30 PM 1.00 TRIP_IN PROD Other RIH; tag cement at 7388'. 01:30 PM 02:30 PM 1.00 ClRC PROD Other Circulate hole clean. 02:30 PM 03:30 PM 1.00 TEST PROD Other Test casing to 3000 psi for 30 minutes; OK. 03:30 PM 11:30 PM 8.00 CLN_OUT PROD Other Drill out cement; shut-off plug & baffle; bypass plug & float collar; & shoe. Clean out rathole. Drill 20' of new hole to 7626' MD; 4396' TVD. 11:30 PM 12:00 AM 0.50 EVAL PROD Making Hole Circulate hole clean. Pump hi-visc sweep & displace hole to new 8.5 ppg mud. Daily Drilling Report: 1C-17 11/23/98 Page 1 Daily Drilling Report ARCO Alaska, Inc. AFC No. Date Rpt No Rig Accept - hrs Days Since Accept/Est: 10,54/7.5 AK9157 11/24/98 12 11/24/98 Rig Relase - hrs: Well: lC-17 Depth (MD/TVD) 8447/4780 Prey Depth MD: 7626 Progress: 821 Contractor: PARKER Daily Cost $ 94833 Cum Cost $1269367 Est Cost To Date $ Rig Name: RIG # 245 Last Csg: 9-5/8"@ 7597' Next Csg: 7"@ 10,503' Shoe Test: 14.1 ppg EMW Operation At 0600: Drilling ahead Upcoming Operations: Drilling ahead MUD DATA DRILLING DATA BIT DATA EH&S : DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL LSND 8447 3HR 4HR N TST 11/24/98 11/23/98 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL VISCOSITY PU WT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 52sqc 240 STC HYC N SPACE 11/09/98 PV/YP SO WT TYPE TYPE TYPE FUEl & WATER 15 / 20 115 FDSS+2CR DS70FGNPV GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 6860 9 / 11 / L88740 20627 APl WL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 250 6.0 7646 11/24/98 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 100 mi/30 min 20 7606 7646 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 4% 15 40 801 1 C-13 PERSONN EL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP oF 6 634bbl !2500111 / 4.18/ lC-17 ~BT PUMP NO WOB 2 WOB 2 RATE (bpm) WIND SPEED 15 12 112131 25- 3 )h LINER SZ RPM 1 RPM I PRESSURE (psi) WIND DIRECTION 45° 8.7 615.515.51 2o- 1425 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR °F -23.23 30.49% 73101721 open .557 Water Base Muds 1000 PIT VOL GPM 2 JETS JETS Fresh Water ARCO PERSONNEL 1 Diesel 7O DAILY MUD SPS 1 BIT COST BiT COST CONTRACTOR 30 $15544 30145 I I RR RR 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $126537 47516001 I 2121bt Irn I I I 1170 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 6 BARO~D 8.91 I I El1 I ERIBNA I I I 20805 PERSONNEL TOTAL 42 TIME I END HOURS I CPS CODE I HOLE SECT I PHASE CPS ] OPERATIONS FROM 0000- 0000 12:00 AM 02:30 AM 2.50 ClRC PROD Other Circ & displace hole wi new mud 02:30 AM 03:30 AM 1.00 CASG PROD Other Perform LOT @ 7626'MD; 4396 TVD, EMW= 14.9 ppg w/8.5 mud 03:30 AM 04:00 AM 0.50 DRIL PROD Making Hole Drilled 7626' to 7646' ADT=0.5hrs 04:00 AM 05:00 AM 1.00 CIRC PROD Other CBU 05:00 AM 06:00 AM 1.00 CASG PROD Other Perform LOT #2 @ 7646' EMW= 14.1 ppg wi 8.5 mud 06:00 AM 10:30 AM 4.50 TRIP_OUT PROD Making Hole Pump Pill, Trip out SLM (no correction) 10:30 AM 11:30 AM 1.00 BHA PROD Making Hole LD BHA #3 11:30 AM 12:30 PM 1.00 BHA PROD Making Hole PU BHA #4, Orient and upload formation recording tools 12:30 PM 03:00 PM 2.50 TRIP_IN PROD Making Hole RIH fill every 25 stds 03:00 PM 03:30 PM 0.50 OTHER PROD Other Service rig 03:30 PM 09:30 PM 6.00 DRIL PROD Making Hole Drilled 7646'-8325' ADT= 3.0 Hi torq 20K 09:30 PM 11:00 PM 1.50 OTHER PROD Making Hole Short trip to shoe I11:00 PM 12:00 AM 1.00 DRIL PROD Making Hole Pump sweep and Drill 8325'-8447' (4780' TVD torq +/- 15K) 24.00 Supervisor:. M.B.WINFREE Daily Drilling Report: lC-17 11/24/98 Page 1 Daily Drilling Report ARCO Alaska, Inc. AFC No. Date Rpt No Rig Accept - hrs Days Since Accept/Est: 11.54 / 7.5 AK9157 11/25/98 13 11/24/98 Rig Relase - hrs: Well: 1C-17 Depth (MD/I'VD) 10530/6344 Prev Depth MD: 8447 Progress: 2083 Contractor: PARKER Daily Cost $105863 Cum Cost $1375230 Est Cost To Date $ Rig Name: RIG # 245 Last Csg: 9-5/8"@ 7597' Next Csg: 7"@ 10,503' Shoe Test: 14.1 ppg EMW Operation At 0600: RIH Upcoming Operations: Finish RIH Circulate LCM. POOH to shoe and rerun LOT. MUD DATA DRILLING DATA BIT DATA EH&S : DRILLSJBOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL LSND 10530 4HR N TST 11/25/98 11/23/98 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 10.9ppg 165 8-1/2" 10/27/98 11/16/98 VISCOSITY PU Vel' MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 63sqc 190 HYC N SPACE 11/09/98 11110/98 PV/YP SO WT TYPE TYPE TYPE FUEL & WATER 29 / 30 150 DS70FGNPV GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 2633 11 / 13 / 20627 APl WL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 1000 3.9 11/25/98 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 100 mi/30 rain 7646 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER:& 13.5% 5000 2884 I C-13 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP oF 10 923bbl 29001 II 4.18/ / 1C-17 MBT PUMP NO WOB 2 WOB 2 RATE (bpm) WIND SPEED 16 18.8 112131 25- 3 oh LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 45° 9.2 615.515.51 20- 1675 LGS i SPM 1 TFA TEA INJECTION FLUIDS CHILL FACTOR °F -19.33 7.4% 17518018o] 1.557 Water Base Muds 3OO PIT VOL GPM 2 JETS JETS Diesel ARCO PERSONNEL 1 520 56511 I 11111111111111 I I Ill 5 11 o DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 30 $29181 3°1451 I 0 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $155716 495160o11 III III 305 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 6 B*RO,D 10.91 I I I11 III 21110 PERSONNEL TOTAL 42 TIME I END HOURSI OPSCODE I HOLESECT iPHASEOPS t OPERATIONS FROM O000:' 0000 : 12:00 AM 11:00 PM 23.00 DRIL SURF Making Hole Drill from 8447' to 10530'. Raised mud wt from 9.2 ppg to 10.9 ppg while drilling from 10200' to 10530'. Lost 45 bbl mud while drilling. 11:00 PM 12:00 AM 1.00 ClRC SURF Making Hole CBU 24.00 Supervisor:. G.R. WHITLOCK Daily Drilling Report: lC-17 11/25/98 Page 1 Daily Drilling Report ARCO Alaska, Inc. i AFC No. Date Rpt No I Rig Accept - hrs Days Since Accept/Est: 12.54 / 7.5 Rig Relase - hrs: AK9157 11/26/98 141 11/24/98 Well: 1C-17 Depth (MD/TVD) 10540/6354 Prev Depth MD: 10530 Progress: 10 Contractor: PARKER Daily Cost $ 81838 Cum Cost $1457068 Est Cost To Date $ Rig Name: RIG # 245 Last Csg: 9-5/8"@ 7597' Next Csg: 7"@ 10,503' Shoe Test: 14.1 ppg EMW Operation At 0600: Running 7" casing Rig on highline 24 hrs Upcoming Operations: Finish running and cementing 7" casing MUD DATA DRILLING DATA BIT DATA : EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL LSND 10530 4RR Y TST 11/25/98 11/23/98 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.8ppg 215 8-1/2" APC 10/27/98 11/16/98 VISCOSITY PU WT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 55sqc 275 HYC N SPACE 11/09/98 11/10/98 PV/YP SO WT TYPE TYPE TYPE FUEL & WATER 19 / 19 165 DS70FGNPV GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 2730 7 / 8 / 20627 APl WL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 1000 4.2 11/26/98 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 100 mi/30 min 17000 7646 INjEcTIoN USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL : WEATHER& 9.0% 2894 lC-13 pERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMp °F 12 972bbl 29001, ,I I 18.57 / 4.25 / lC-17 MBT PUMP NO WOB 2 WOB 2 RATE (bpm) W~ND SPEED 18 17.5 112131 25- 4 ah LINER SZ RPM 1 RPM I PRESSURE (psi) WIND DIRECTION 45° 8.4 615.515.51 20- 1600 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR °F -19.20: 6.8% 7518018o1 .557 Waler Base Muds 675 PIT VOL ~ GPM 2 JETS JETS Fresh Water ARCO PERSONNEL 1 650 5651 I I 11111111111111 IIIII too 11 Diesel 65 DAILY MUD SPS 1 BIT COST BIT COST 'CONTRACTOR 30 $2416 30145J J 0 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $158134 49516ool I III III ~4o COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 6 BAROID 10.9111 III III 2195o PERSONNEL TOTAL 42 TIME J END HOURS J OPS CODE J HOLE SECT J PHASE OPS J OPERATIONS'FROM 0000- 0000 12:00 AM 02:00 AM 2.00 ClRC PROD Making Hole Circ. Flow check-slight flow. CBU w/no gas back to surface. Well breathing. 02:00 AM 03:30 AM 1.50 WIPERTRP PROD Making Hole POOH to shoe. 03:30 AM 04:30 AM 1.00 CIRC PROD Making Hole CBU 04:30 AM 05:30 AM 1.00 TEST PROD Making Hole Perform LOT to 11.7 ppg EMW 05:30 AM 06:30 AM 1.00 WIPERTRP PROD Making Hole RIH 06:30 AM 07:30 AM 1.00 ClRC PROD Making Hole Break circ slowly wi partial returns. Lost all returns. Pumped a total of 200 bbls losing 75 bbls. 07:30 AM 09:30 AM 2.00 WIPERTRP PROD Making Hole POOH to shoe 09:30 AM 12:30 PM 3.00 ClRC PROD Making Hole Circ and reduce mud wt. to 9.8 ppg 12:30 PM 01:30 PM 1.00 WIPERTRP PROD Making Hole Trip in hole to 8734' 01:30 PM 02:30 PM 1.00 ClRC PROD Making Hole CBU reducing mud wt. to 9.8 ppg 02:30 PM 03:00 PM 0.50 WIPERTRP PROD Making Hole RIH to 9664' 03:00 PM 04:30 PM 1.50 CIRC PROD Making Hole CBU reducing mud wt. to 9.8 ppg 04:30 PM 05:00 PM 0.50 WIPERTRP PROD Making Hole RIH tp 10530' 05:00 PM 07:00 PM 2,00 ClRC PROD Making Hole CBU reducing mud wt. to 9.8 ppg 107:00 PM 07:30 PM 0.50 DRIL PROD Making Hole Dril from 10530' to 10540' 07:30 PM 09:00 PM 1.50 ClRC PROD Making Hole CBU monitor well 09:00 PM 11:00 PM 2.00 TRIP_OUT PROD Making Hole POOH-stand back 70 stds d.p. 11:00 PM 12:00 AM 1.00 TRIP_OUT PROD Making Hole POOH-laydown drillpipe Daily Drilling Report: 1C-17 11/26/98 Page 1 Daily Drilling Report ARCO Alaska, Inc. AFC No. Date Rpt No I Rig Accept - hrs Days Since Accept/Est: 13.54/7.5 :Rig Relase - hrs: AK9157 11/27/98 151 11/24/98 Well: 1C-17 Depth (MD/TVD) 10540/6354 Prev Depth MD: 10540 Progress: 0 Contractor: PARKER Daily Cost $105650 Cum Cost $1562718 Est Cost To Date $ Rig Name: RIG # 245 Last Csg: 7"@ 10540' Next Csg: 4-1/2"@ 10,912' Shoe Test: 14.1 ppg EMW Operation At 0600: Rigging up to test DOPE Rig on highline 24 hfs Upcoming Operations: Test DOPE, M/U bha. RIH P/U d.p. Drill float equipment and run LOT. Drill ahead MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL LSND 4PR N TST 11/25/98 11/23/98 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.7ppg 8-1/2" 10/27/98 11/16/98 VISCOSITY PU WT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 52sqc HYC N SPACE 11/09/98 11/10/98 PV/YP SO WT TYPE TYPE TYPE FUEL & WATER 19 / 20 DS70FGNPV GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 2656 7 / 8 / 20627 APl WL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 250 4.6 11/27/98 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLEWATER 100 mi/30 min 7646 INJECTI°N USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 8.0% 2894 I C-13 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP °F 10 403bb, 29001 I I 18.57/4.25 / lC-17 MBT PUMP NO WOB 2 WOB 2 RATE (bpm) WIND SPEED 0 19 112131 25- 0 )h LINER SZ RPM I RPM I PRESSURE (psi) WIND DIRECTION 0° 9.2 615.515.51 2o- o LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR °F 10.00 4.4% 7518ol8ol .557 0 PiT VOL GPM 2 JETS JETS ARCO PERSONNEL 1 65o 56511 I 11 II1111111111 IIIII o DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 30 $525 301451 [ 0 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $156669 49516001 I 311 I btln I I I 0 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 8 BARO~D 10.91 I I x 101no ltd [ I I 21950 PERSONNEL TOTAL 44 TIME I END HOURS I OPS CODE I HOLE SECT I PHASE OPS I OPERATIONS FROM 0000- 0000 12:00 AM 02:00 AM 2.00 TRIP_OUT PROD Casing and Finish Ed d.p. Stand hwdp back in derrick Cementing 02:00 AM 03:30 AM 1.50 BHA PROD Casing and L/D d.c's and download mwd. Cementing 03:30 AM 05:00 AM 1.50 CASG PROD Casing and Pull wear ring. R/U casers. Hold safety meeting Cementing 05:00 AM 05:00 PM 12.00 CASG PROD Casing and Run 7" casing to 10540'. Circulated 1 casing volume every Cementing 50 jts. 05:00 PM 05:30 PM 0.50 CASG PROD Casing and PJD fillup tool and M/U cmt head. Cementing 05:30 PM 06:30 PM 1.00 CIRC PROD Casing and Circulate and condition mud. Pump 600 bbls. Cementing 06:30 PM 08:30 PM 2.00 CEMENT PROD Casing and Cement casing: Test lines to 3500 psi. Pump 20 bbl Cementing preflush, 40 bbl Arco spacer @ 12 ppg, drop plug and pump 36 bbl slurry at 15.8 ppg, drop top plug. Pump 20 bbl H20 and displace w/380.4 bbl mud. Bump plug w/1900 psi. Checkfloats-OK. ClP @ 20:15. 08:30 PM 10:00 PM 1.50 NU_ND PROD Casing and N/D stack. Set slips w! 250 K indicator wt. Cutoff casing. Cementing L/D cutoff. Set back stack ~10:00 PM 12:00 AM 2.00 CASG PROD Casing and R/D casing elevators and prep floor for 3-1/2" d.p. Dress 7" Cementing casing stub, Daily Drilling Report: 1C-17 11/27/98 Page 1 CASING TEST and FORMATION INTEGRITY TEST Well Name: 1C-17 Date: 2/25/99 Supervisor: Mike Winfree (Re-tested annulus after rig release with Hot Oil Unit) Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8", 40 ppf, L-80, BTC Casing Setting Depth: 7,597' TMD 4,381' TVD Hole Depth: 7,597' TMD 4,381' TVD Mud Weight: 6.8 ppg Length of Open Hole Section: 0' EMW = Leak-off Press. + Mud Weight 0.052 x TVD = 1,400 psi + 6.8 ppg 0.052 x 4,381' EMW for open hole section = 12.9 ppg Pump output = 0.1000 bps Fluid Pumped = 8.0 bbl TIME;UNE ~ ;; 1,500 psi 1,400 psi 1,300 psi 1,200 psi 1,1 O0 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 1 O0 psi 0 psi 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 58 60 62 64 66 68 70 72 74 76 78 80 82 84 86 88 90 92 94 96 stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE ......................................................................0 stks 350 psi ~3--~;!:~ ........ -~-~i .... -~' ~ 10 stks 600 psi ~ 20 stks 1,050 psi i ................. -3--°-_.s-t.-k_.s___-.-l_,..3.s--°-.-P.~ L. L ................ ~_o___s_t_Ls__~ j_,._4.o__o__p_~L, i .__s_.o___s_t__k__s__ _ !,._~.o_.o__ p__s_L ! L ................................................ ! ! 1 ................................................. ............... ~ ................................ 4 SHUT IN TIME SHUT IN PRESSURE [--'~'.~-~-r,~ .................. F-'~-;x~-~,'-~r-! !---~;~-~-f,~- ................ T-¥;~-~'6'i~i'i L__2:.o...mj.n_ ................. LJ_d.o_.o._p_s.L! ,.._.a_..o___mj_n. ................. ," _!,.?ZS..p_?.Li 4.0 min i 1,050 psi i ____5_._o___m__,_n_ ................. ,_!,__o~.o._p_.s_,_~ ____6_._O__.m..i.n_ .................. 1. _1. ,_ .0_5_ _0_..P_ .s_ L i ,.i. ,._Z.._o___m__Ln_ ................. ±_!,__°~.°..P..s. Lj i i ................ i ................................ ! ................ ................ I.. ............... ,i, ................. i I SHUT IN TIME SHUT IN PRESSURE '--~76--~ih- ........................ f~'r~TX .... '-')-]6--r~ih- ................................... , 2.0 min., i. ._.~...o...m.L_n. .................................. 4.0 mJn 5.0 mJn 6.0 min ................ i. ............... ,i. ................ .i. i i 7.0 min , , 8.0 min : "'~;'6'-r~ih---i' ................................. lO.O rain: ":f§-]6'-r~i~--r ............... [ ................ "'~[::;:6"r~ifi--[ ............... [ ................ i 8.0 min i i 1,050 psi ............... t- .............. ,-I- ................ 9.0 min : ~ 1,025 psi · i i ' i .__]_o__._o___m_j_n__ ,_ .............. _~ _ _1_,_ _o_2__s_ _ _p_ _s_, _.,, ._.3_.0_..9_. _m_Ln__ NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 3, 1999 Mr. Blair E. Wondzell, P.E. Senior Petroleum Engineer State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Additional Injectivity Test for Annular Injection Request on KRU 1C-17 Dear Blair, Attached please find the leak-off test form (dated 2/25/99) documenting the pump-in test performed on the 9-5/8" x 7" annulus to confirm formation adequacy for annular injection. The pump-in test was performed using diesel pumped by a Hot-Oil unit after Parker #245 had moved off the well. This test had been delayed due to the severe cold period experienced during late January and early February of this year. Please call me at 265-6120 if you have any questions regarding this request. Graham L. (Chip) Alvord Kuparuk Drilling Engineering Supervisor ARCO Alaska, Inc. Drilling Attachments: Leak-off Test Form lC- 17 (2/25/99) ARCO Alaska, CONDUCTOR (0-121, 0D:16.000, Wt:62.58) NIP (512-513, OD:4.470) TUBING (0-10316, OD:3.500, ID:2.992) PRODUCTION (0-10540, OD:7.000, Wt:26.00) SURFACE (0-7597, 0D:9.625, Wt:40.00) Gas Lift andrel/Dummy Valve 1 (10229-10230, OD:6.018) NIF (10277-10278, 0D:4.470) SEAL (10316-10317, OD:6.900) LINER (10312-10969, OD:4.500, Wt:12.60) Perf (10690-10720) Inc. .. KRU 1C-17 lC-17 APl: SSSV Type: Annular Fluid: 500292287200 Reference Loq: Last Taq: Last Tag Date: Casing String - ALL Size Top 16.000 0 9.625 0 7.000 0 4.500 10312 Orig Compltn: 112_/2/98 Ref Log Date:[ TD: 10969 ftKB Max Hole Angle: 65 deg @ 2967 Bottom TVD 121 121 Tubing String - TUBING Size Top 3.500 0 7597 4380 1054o 6354 10969 10969 Bottom TVD 10316 6145 Angle @ TS: 120 deg @ 10685 Angle @ TD:I20 deg @ 10969 Rev Reason:I NEW SCHEM BY Last Update: 1E/Z19/99 Wt Grade Thread 62.58 H-40 WELDED 40.00 L-80 BTC 26.00 L-80 BTC-MOD 12.60 L-80 NSCT Wt Grade Thread 9.30 L-80 ABM-EUE Perforations Summary Interval TVD Zone Status Feet SPF~ Date[ Type I Comment 10690- 10720 6495-6523 C-4,C-3 30 4~12/25/9~ IPERF 12.5" HO BH, 180 PH Gas Lift Mandrels/Valves Stn MD TVD Man I Man V Mfr VType V OD Latch Port TRO Date VIv Mfr Type Run Commen 1 10229 6065 CAMCO MMM CAMCO DMY 1.5 RK 0.000 0 12/3/98 Other (plugs, equip., etc.) -JEWELRY Depth I TVDI Type CAMCO DS NIPPLE Description ID 5121 5091 NIP 2.812 10277 61091 NIP CAMCO D NIPPLE 2.750 10316 6145 SEAL BAKER GBH-22 2.992 -_ _J ARCO Alaska, Inc. FACSIMILE .TRANSMISSION ..... I III _. II Number of Pages (Cover +): . ~ ~ ~hon~: ~6~- ~/~ ...... Copi~ TO' ._ ~ ,,.; , ..... Subject: FAX #: Phone #: Kuparuk Development P. O. BOX 100360 ANCHORAGE, AK 99510-0~i60 FAX # 907 265-6224 ATO-1279 i i -:_ ii1 ZT(,, .-7ff42_ I-I I:t I I__1__ I IM G S E I:1 ~/I I-- I:: S 08-Dec-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well lC-17 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 10,969.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) DEC 0O ~998 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company STATE OF ALASKA ALA~.~.A OIL AND GAS CONSERVATION COM,~oSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend -- -- Alter casing Repair well _ Change app~ved program __ Pull tubing-_ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1395' FNL, 563' FWL, Sec. 12, T11N, R10E, UM At top of productive interval 36' FNL, 1821' FWL, Sec. 2, T11N, R10E, UM At effective depth At total depth 55' FSL, 1768' FWL, Sec. 35, T12N, R10F, UM Operation Shutdown Plugging Re-enter suspended well Time extension Stimulate - Variance__ Perforate__ -- Other X Annular Injection 6. Datum elevation (DF or KB) 41' RKB feet 5. Type of Well: Development -- Exploratory -- Stratigraphic__ Service X -- 7. Unit or Property name Kuparuk River Unit 8. Well number 1C-17 9. Permit number 98-224 10. APl number 50-029-22872 11. Field/Pool Kuparuk River 12. Present well condition summary Total Depth: measured 10969 feet (approx) true vertical 6757 feet Effective depth: measured 10455 feet (approx) true vertical 6300' feet Casing Length Structural Conductor 80' Surface 7556' Intermediate Production 10499' Liner 657' Perforation depth: measured N/A true vertical N/A Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 10342' Packers and SSSV (type and measured depth) Baker ZXP Liner Pkr @ 10312' MD Size 16" 9.625" 1! Plugs (measured) None Junk (measured) Cemented Measured depth True vertical depth 9 cubic yards 121' 121' 930 sx AS III LW & 7597' 4381' 670 sx Class G & 60 sx AS I 175 sx Class G 10540' 6354' 112 sx Class G 10969' 6757' ORIGINAL A a. ska 8iJ & Co; s, Commission Anchorage, 13. Attachments Description summary of proposal Detailed operation program BOP sketch Contact Chip Alvord at 265-6120 with any questions. LOT-test, surface cement details and casing deta~q'sheets X -- __ 14. Estimated date for commencing operation December 1998 Oil 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing ~s true and correct to the best of my knowledge. Signed ~ ~ ~ Title Kuparuk Team Leader FOR COMMISSION USE ONLY 15. Status of well classification as: Gas Suspended Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance__ Mechanical In~grity Test Subseque~form require 10- Approved by the order of the Commission Form 10-403 Rev 06/15/88 ORiGiNAL SIGNED BY Robert N. Chdstenson - - Commissioner Date /,:~ SUBMIT IN TRIPLICATE CASING / TUBING / LINER DETAIL 9-$/8" Surface Casing ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL: 1C-17 KRU DATE: 11/22/98 1 OF 1 PAGES # ITEMS 65 Jts Joint 'B' Joint 'A' 127 Jts 1 Jt 2 Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN RKB to Landing Ring - Parker Rig #245 FMC Gen 4 Fluted Mandrel Casing Han~er & pup 9-5/8", 40#, L-80, BTC Casing (Joints #131 -#195) 9-5/8", 40#, L-80, BTC Casing - Baker Locked Gemoco '754' Stage Cementin~ Tool 9-5/8", 40#, L-80, BTC Casing - Baker Locked 9-5/8", 40#, L-80, BTC Casing (Joints #4 - #130) Gemoco Insert Shut-Off Baffle 9-5/8", 40#, L-80, BTC Casing Gemoco Float Collar (Joint #3) 9-5/8", 40#, L-80, BTC Casing Gemoco Float Shoe (Joints #1 & #2) LENGTH 40.35 2.26 2507.85 41.70 DEPTH TOPS 40.35 42.61 2550.46 2.76 2592.16 38.96 2594.92 4844.91 37.26 1.45 77.60 1.70 2633.88 7478.79 7478.79 7516.05 7517.50 7595.10 Bottom of Shoe ==>> 7596.80 I TD of 12-1/4" Hole = 7606" MD (~ 10' of Rathole) I Baker Lok thru Insert Shut-Off Baffle, plus Sta~le Collar to Joints 'A ' & 'B' Install Insert Shut-Off Baffle in Connection on Top of Joint #3 Run Sta~le Collar & Baker Lok'd Jts 'A ' & 'B' on Top of Joint #130 Run FMC Hanger on Top of Joint # 195 43 BOW $orina Centralizers: 1 / Jt on first 15 joints, first 2 on stop rin~! in middle of joint; Then 1'eve-ry 3rd joint on Joints #18, 21, 24, 27, 30, 33, 36, 39, 42, ~5, 48, 51, 54, 57, #60, 63, 66, 69, 72, 75, 78, 81, 84, 87, 90, 93, 96, & 99. 2 Riaid Straiaht Blade Centralizers: Slide I on Jt 'A' & Jt 'B' Leave OUT 10 ioints: #196 thru #205 Remarks: String Weights with Blocks: 310K# Up, 130K# Dn, 75K# Blocks. Ran 97 joints of casing. Drifted casing with 8.679" plastic rabbit. Used Arctic Grade APl Modified No Lead thread compou on all connections. Torqued connections to the base of the triangle stamp. Parker Rig #245 Drillin~l Supervisor: Don E. Breeden ' IIF ARCO Alaska, Inc. Well Name: lC-17 Report Date: 11122/98 Report Number: 10 Rig Name: RIG # 245 AFC No.: AK9157 Field: Kuparuk River Unit Cementing Details Casing Size Hole Diameter: Angle thru KRU: I Shoe Depth: I LC Depth: % washout: 9-5/8" 12-1/4" 62* slantI 7597' MD/4381' 'I'VDI 7479' MD Centralizers State type used, intervals covered and spacing Comments: 43 Gemoco Bow Springs: One on each of first 15 joints, first two on stop dng in middle of joint; Then one every third joint thru oint #99. 2 ROTCO Rigid Sraight Blade Centralizers: On middle of joint on each side of Stage Collar at 2592' MD. Mud Weight: PV(prior cond): PV(after cond): I YP(prior cond): YP(after cond): Comments: 10.4 ppg 38 30I 43 30 Visc: 98 sec to 70 sec Gels before: Gels after: Total Volume Circulated: 15/33 11/35 1743 Bbls Wash 0 Type: Volume: Weight: Comments: ARCO Wash 20 Bbls 8.34 ppg 1st Stage Spacer 0 Type: Volume: Weight: Comments: ARCO 40 Bbls 130 Bbls water 10.5 ppg 18.34 ppg 1st Stage I 2nd Stage Lead Cement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: AS III LW 75* F 330 sx / 600 sx 10.7 ppg 4.44 cfs 1st Stage 12nd Stage Additives: Class G + 9% D44 + 0.6% D46 + 30% D53 + 1.5% D79 + 50% D124 + 1.5% Sl Tail Cement 0 Type: Mix wit temp: I No. of Sacks: Weight: I Yield: Comments: Class G I AS I 75* FI 670 sx / 80 sx 15.8 ppg / 15.7 PPgI 1.17 cfs / 0.93 cfs 1st Stage 12nd Stage ~,dditives: Class G + 1.0% S1 + 0.2% D46 + 0.3% D65 II Arctic Set I Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 8.3 BPM 17.2 BPM 7.8 BPM 17.2 BPM 310K# (75K# Blocks) 1st Stage 12nd Stage Reciprocation length: Reciprocation speed: Str. Wt. Down: -15' -20 fpm 130K# (75K# Blocks) Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 567 Bbls 1196 Bbls 568 Bbls / 197 Bbls 147K# Calculated top of cement: CP: Bumped plug: Floats held: Cemented to Surface Date:Ill22/98 Yes ! Yes Yes/Yes Time:13:30 / 17:30 Remarks: Circulated to condition hole & mud for cementing. Circulated 1743 Bbls, 8.5 BPM final rate, 600 psi. Reduced funnel viscosity from -100 sec to -70 sec, MW from 10.5+ ppg to 10.4 ppg. Reciprocated casing while circulating, 310K# - 335K# Up, 135K# Down. 1st Stage Cement Job: Dowell flush lines with 5 Bbls water. Test lines to 3500 psi. Pump 20 Bbls ARCO Wash, 5.5 BPM, 300 psi. Pump 40 Bbls, 10.5 ppg ARCO Spacer, 5.5 BPM, 350 psi. Mix & pump 263 Bbls, 330 sx, 10.7 ppg AS III LW Lead Cement, 7.1 BPM, 300 psi. Load & drop bypass plug. Mix & pump 129 Bbls, 15.8 ppg Class G Tail Cement, 7.0 BPM, 300 psi. Load & drop shut-off plug. Chase plug with 6 Bbls Tail Cement (670 sx total Tail). Follow with 24 Bbls wash-up water. Switch to rig pump & finish displacement with 538 Bbls mud, 8.3 BPM to 7.8 BPM, 300 psi to 1400 psi. Slowed rate to 4.6 BPM, 1250 psi to bump plug. Bumped plug & pressured up to 1550 psi. Bled off & checked floats, OK. Reciprocated casing until 10 Bbls before spacers reached shoe, pipe getting sticky about 5' up, pulling a little more each time to pull through next 5', up to 380K#; also losing more weight down. Tded once more up to 400K#, then set down on hanger & left set. Had full returns throughout. 1st Stage ClP ~ 1330 hrs, 11/22/98. Pressured up & opened stage tool at 2592' MD, 1998' TVD. Stage tool opened at 2850 psi. Circulated hole clean through stage tool & reconditioned mud for 2nd stage cementing. Circulated 626 Bbls total, 8.1 BPM final rate, 375 psi. Circulated out 60 Bbls of spacers & about 160 Bbls of Lead Cement & cement contaminated mud. 2nd Stage Cement Job: Dowell prime up & pump 5 Bbls water, test lines, pump 25 Bbls more water. Mix & pump 459 Bbls, 600 sx, 10.7 ppg AS III LW Lead Cement, 7.1 BPM, 300 psi. Saw water flush, then cement contaminated mud at 430 Bbls pumped. Had 10.7+ ppg Lead Cement returns at 444 Bbls pumped. Switched to Tail at 459 Bbls Lead Cement pumped. Mix & pump 10 Bbls, 60 sx, 15.7 ppg Arctic Set I Tail Cement, 2.8 BPM, 250 psi. Drop closing plug & chase with 20 Bbls wash-up water, 6.8 BPM, 300 psi. Switch to rig pump & finish displacement with 177 Bbls mud, 7.2 BPM, 550 psi. Slowed to 5.3 BPM, 450 psi to bump plug. Bumped plug. Pressured up & saw stage tool close at 1200 psi. Pressured up to 2200 psi & held 5 minutes, OK. Bled off & checked floats, OK. Had good 10.7 ppg to 11.0 ppg Lead Cement returns to surface (approx. 220 Bbls). Had full returns throughout. 2nd Stage CIP (~ 1730 hrs, 11122/98. i Cement Company: Rig Contractor: Parker Approved By: Don E. Breeden Dowell Mud Comments: Visc: 98 sec to 70 sec Wash 0 Comments: 1st Stage Spacer 0 Comments: 1st Stage 12nd Stage Lead Cement 0 Comments: 1st Stage 12nd Stage oint #99. 2 ROT~O Rigid Sraight Blade Centralizers: On middle of joint nn each side of Stage Collar at 2592' MD. Weight: PV(prior cond): 10.4 ppg 38 Gels before: Gels after: 15133 11135 Type: ARCO Wash Type: ARCO I Type: ] Mix wtr temp: AS III LW I 75* F Tail Cement 0 Comments: 1st Stage / 2nd Stage Additives: PV(after cond): YP(prior cond): 30 '~ ~J 43 I Total Volume Circulated: 1743 Bbls Volume: 20 Bbls Volume: Weight: 8.34 ppg Weight: YP(after cand): 30 40 Bbls / 30 Bbls water No. of Sacks: 330 sx 1600 sx Weight: 10.7 ppg 10.5 ppg i 8.34 ppg Yield: 4.44 cfs Class G + 9% D44 + 0.6% D46 + 30% D53 + 1.5% D79 + 50% D124 + 1.5% S1 Type: Mix wtr temp: I No, of Sacks: Class G I AS I 75* F I 670 sx / 60 sx Weight: 15.8 ppg 1 15.7 ppg Yield: 1.17 cfs 10.93 cfs Additives: Class G + 1.0% S1 + 0.2% D46 + 0.3% D65 II Arctic Set I Displacement 0 Rate(before tail at shoe): Rate(tail arouna shoe): Str. Wt. Up: Comments: 8.3 BPM 17.2 BPM 7.8 BPM 17.2 BPM 310K# (75K~ Blocks) 1st Stage I 2nd Stage Reciprocation length: Reciprocation speed: Str. Wt. Down: -15' -20 fpm 130K# (75K# Blocks) Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 567 Bbls I 196 Bbls 568 Bbls I 197 Bbls 147K# Calculated top of cement · Cemented to Surface CP: Date:Ill22/98 Time:13:30 / 17:30 Bumped plug: Floats held: Yes I Yes Yes/Yes Remarks: Circulated to condition hole & mud for cementing. Circulated 1743 Bbls, 8.5 BPM final rate, 600 psi. Reduced funnel viscosity from -100 sec to -70 sec, MW from 10.5+ ppg to 10.4 ppg. Reciprocated casing while circulating, 310K# - 335K# Up, 135K# Down. 1st Stage Cement Job: Dowell flush lines with 5 Bbls water. Test lines to 3500 psi. Pump 20 Bbls ARCO Wash, 5.5 BPM, 300 psi. Pump 40 Bbls, 10.5 ppg ARCO Spacer, 5.5 BPM, 350 psi. Mix & pump 26_~.~3..~b_~.,.~_3~3_.0..s3,,10.7 ppg AS III LW Lead Cement, 7.1 BPM, 300 psi. Load & drop bypass plug. Mix & pump 129 Bbls, 15.8 ppg Class G Tail Cement, 7.0 BPM, 300 psi. Load & drop shut-off plug. Chase plug with 6 Bbls Tail Cement (670 sx total Tail). Follow with 24 Bbls wash.-up water. Switch to rig pump & finish displacement with 538 Bbls mud, 8.3 BPM to 7.8 BPM, 300 psi to 1400 psi. Slowed rate to 4.6 BPM, 1250 psi to bump plug. Bumped plug & pressured up to 1550 psi. Bled off & checked floats, OK. Reciprocated casing until 10 Bbls before spacers reached shoe, pipe getting sticky 'about 5° up, pulling a little more each time to pull through next 5', up to 380K#; also losing more weight down. Tried once more up to 400K#, then set down on hanger & left set. Had full retums throughout. 1st Stage ClP (~ 1330 hrs, 11122J98. Pressured up & opened stage tool at 2592' MD, 1998' 'I'VD. Stage tool opened at 2850 psi. Circulated hole clean through stage tool & reconditioned mud for 2nd stage cementing. Circulated 625 Bbls total, 8.1 BPM final rate, 375 psi. Circulated out 60 Bbls of spacers & about 160 Bbls of Lead Cement & cement contaminated mud. 2nd Stage Cement Job: Dowell prime up & pump 5 Bbls water, test lines, pump 25 Bbls more water. Mix & pump 459 Bbls, 600 sx, 10.7 ppg AS III LW Lead Cement, 7.1 BPM, 300 psi. Saw water flush, then cement contaminated mud at 430 Bbls pumped. Had 10.7+ ppg Lead Cement returns at 444 Bbls pumped. Switched to Tail at 459 Bbls Lead Cement pumped. Mix & pump 10 Bbls, 60 sx, 15.7 ppg Arctic Set I Tail Cement, 2.8 BPM, 250 psi. Drop closing plug & chase with 20 Bbls wash-up water, 6.8 BPM, 300 psi. Switch to rig pump & finish displacement with 177 Bbls mud, 7.2 BPM, 550 psi. Slowed to 5.3 BPM, 450 psi to bump plug. Bumped plug. Pressured up & saw stage tool close at 1200 psi. Pressured up to 2200 psi & held 5 minutes, OK. Bled off & checked floats, OK. Had good 10.7 ppg to 11.0 ppg Lead Cement returns to surface (approx. 220 Bbls). Had full returns throughout. 2nd Stage CIP ~ 1730 hrs, 11122J98. Cement Company: I Rig Contractor: Dowell I Parker Approved By: Don E. Breeden CASING TEST and FORMATION INTEGRITY TEST Well Name: Supervisor: 1C-17 Don E. Breeden/M.B. Winfree 9 5/8", 40.0 ppf, L-80, BMTC Date: 11/24/98 Casing Size and Description: Casing Setting Depth: Mud Weight: 8.5 ppg Hole Depth: 7,626' TMD 7,597' TMD 1,473 psi + 8.5 ppg EMW LOT = (0.052 x 4,381') = 15.0 ppg Fluid Pumped = 5.0 bbl 4,381' TVD EMW = Leak-off Press. + MW 0.052 x -FVD Pump output = 0.1000 bps _,__P~.II~~ ~ [IIIIIII_LII[Illl IIIIIIII :.- ,'B- 2_,o~ps. iii I I I ~ I-I--1-1 I I I I I I lll J~'F I '11 III I [11 II I ii II I ?~P~'I-I I I J I J I I J I I I J~illlll~lllllllllil Illl Jl ill J Il J JJ !'i~gi/Ill ' JJ JJJJJJJJJ 2'000 psil I llJlllllllllJll larl I I ' ~l~l I J I "1~i~;'t~:_~.._~'.~ ~ ¢ ~, ~ ~1 I I I I I I I I I I I I I ,uup illIIlll i illlllllllllll IJIll/I 1 600 psi ~1'~c~P'J I I I I I I I I J I I Ii I i i~l-~'T-t-r-~.;L -.~--LEAK-OFF TEST · jj i-i-I J I I I I iJJlll:l~lllllllll 1 100ps *= I lllllll CASING TEST ,. , .,,,,,,, ,,,,., 7rtnKsl I i ~ i I I I I I ~ I I I I I I I J I I I I I I J % J-J-L-~ TIME LINE 14-I-M-J :~,'. IJ~"TIIII Illllllllll IIl':rlll~ ....... _%2W~Ps!~iJ,~liiiiiiilJlilliilJIIIillliiIll IJIlilil LL_IIIIIIIIlll .u~_m!l II II I/CT-rtl Ill i ii i il i i~ i i i ii i i ii jl i ii i i JlJl ii ill ii i i ii i ii i i i i i i loo~,~]~i~'FI I _ID I I I I I _L o~JI I'TI I I I .......................................... 0 2 ~ 6 8 10121`1~6~2~222~262~3~323436~84~`~2ad`~6485~$26456~7~727~767~2~9~~M~2~2~2 st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st 0 2 4 6 8 0 2 k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k ststststst ststst stststst st kkkkkkkkkkkkk STROKES LEAK-OFF DATA MINUTES FOR FIT STROKES PRESSURE ! 0 stks i 0 ~si .................. ~ .................... + .................. J 4stks j 106 psi ................... i ..... -g~i-~; .... T .... ~'8'YbTi--"i', ................... 1 .... -r~-;i-~ .... T .... r~-~--~-~-i--i .................... i .... i-/i-~'i~ .... T .... ~6'6"~-~-i'"'i i 24stks i 820 psi .................... i .... -~-~-~i-~ .... T .... ~'~'~"~'~¥'"1 .................... i .... '~'~'~i~$ .... T--'C6iiTi;~;F-i .................... ~ .................... -P ...................-t i 40stks i 1,332psi .................... 1 .... '~,-,i-~i-lii; .... .................... 't ....................-1- ................... -I i 48stks j 1,490psi j .................... ~ .................... T ................... .................... ! .................... T ................... .................... ," .................... 4- ................... 4 i '., _.: I I I .................... i .................... ,,t ................... i .................... -I .................... + ................... I .................... ., .................... ,._ ................... j I j .................... ~ .................... + ................... 4 I I I SHUT IN TIME j SHUT IN PRESSURE 1.0min i i 1,370psi 5.0min ! i 1,075psi j ..... ~':'6'~i;-,' .... i .................... T .... ~"~'~'i;-~T"j .................... · ~ ....................-r' .................... .... .9_...o..mLn. .... i .................... L._.-e_Zg._-P?-.L-_J 11.0min i i 875 psi 15.0min i ~ 840 psi F-'~-EiS--~;f~----i .................... T .... f~'6"/:,-~i'"'i F-"~'~:~'~;','--i .................... i .... ~'~'--,~'~"'"'] Eii¢]5~iEEiiEZZZiiiiiiZ,~ Zi?iEiEEiiiJ CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ! 0 stks J 0 Esi ,'- .................. ~ .................... 'l .................. : 4stks i 125psi i ................... i ..... ~-~'~ ..... ,,= .... ~-~-6--~-~¥---i ~ .................... t .................... 'I .................... -I i 12stks i 450 psi [ .................... i .... ii~-~iiE~ .... i ..... ~'6-6'-6'~i'-'-i [iiiZiZiiiiiiiZiiiiii.E~!iEiiiiZiiEEOEZ] i 24stks i 950 psi f .................... i .... '~-g;i'~; .... .T'"i;h'Sii-~;'f"i i 32stks j 1,275psi J- .................... 't ....................'l .................... -I i i 40stks i 1,625psi r .................... ! .... '4~i';i'~i; .... ! i 48stks i 2,025 psi [ .................... l .... '~-~;i-~; .... i---~;~-i:;~-f--i , I 60stks j 2,625 psi l [iiiiZiiiZiZZ[Z33iEEiii[i~;~_)!31Eii~ i ! 68stks i 3,025 psi ! i .................... i .................... i .................... } .................... 3, .................... I I J SHUT IN TIME! ~, ,'- .................... 'l' .................... -I .................... i 0.0min j ! 3,025 psi f .... -G-~i~,- .... i .................... i .... EiS-TriB' .... ] .................... ; .................... ; .................... 4 .................... 4 j 3.0min i ! 1,970psi ! 5.0min i i 1,950psi ! i 7.0min i i 1,940psi ! i .... -~:~'~' .... i .................... i'"'~;~'~;F-i r .... E'6-~iA' .... 1 .................... i'"'ii~§~'~'i"i i ..................... 10.0 min ~ .................... i---i-;~i~6-~;i--! ,'- .................... 'l' .................... '1 .................... I 15.0min j I 1,920 psi r--~Ei~-~F~----! .................... ['"'~E~'~i~'"'i .................... i----~;~-~-i"i r'"-ff616'~[;-,-'"~ .................... i'--i';~$66-~'i"i L ....... -' ............ ; .................... ., ....................-, NOTE: STROKES TURN TO MINUTES DURING "sHuT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: Supervisor: 1C-17 G.R. Whitlock 9 5/8", 40.0 ppf, L-80, BMTC Date: 11/25/98 Casing Size and Description: Casing Setting Depth: Mud Weight: 10.9 ppg Hole Depth: 6,344' TVD 7,597' TMD 254 psi + 10.9 ppg EMW LOT = (0.052 x 4,381') = 11.7 ppg Fluid Pumped = 3.4 bbl 4,381' TVD EMW -- Leak-off Press. + MW 0.052 x TVD Pump output = 0.1000 bps ~'b~g ..................................................................................... 2',300 psi 2,200 psi 2,1 (30 psi 2,000 psi 1,900 psi ......................... 1,800 psi ................... 1,700 psi 1,600 psi 1,400 pSI - 1,500 psi - ---- 1 300 psi 1'200 psi. ~3Ii ~ L_'EAK-QFF TEST '- - ' -F-t~-I-k-I-I-q-II --~--CASING TEST 1.,,_,, p,, --rn~~-r-~-r~-, ....... I-I-I-I-I 1,000 psi. ~-h-k-k-I-h'll .......... LOT SHUT IN TIME I-I-I-I-1 900 psi - ,. .... ~-I~t--rl-~-r-ll -~ CASING TEST SHUT IN TIME ~UU pSI ~~'~'--"~--" ...... 700psi '~F~~~F~I~~--~3[~~I : TIME LINE l-'~--~-I 600 psi -- ..................... 500 psi .... - .............................. 400 psi, -- - ................ 300 psi 200 psi .............................. 0 2 4 6 8 10 1214 16182022242628303234363840424446485052545658,5062 6466687072 74 7678808284868890929496981010 10 101011 st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st 0 2 4 6 8 0 k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k kststsfst;tst k k k k k STROKES LEAK-OFF DATA MINUTES FOR FIT STROKES PRESSURE 2 stks i 45 psi .................... · ~ .................... -~- ................... -~ 4stks i 120 psi ........................... ~--a-~ ..... T .... ¥~'~"~,'~T---1 , ......................... .L°-~-t-k--s- .... L .... -2-9--3--P-S--i-----J .......................... j..2..s_.t_k_.s_ .... : .....2..t4_._p_s_!__J ~ ......................... j_.4__s_.t.k_.s_ .... jj_ .... _2._2_9___p._sL .... .......................... J.6___s__t_k_.s. .... L...._2._2..6__p_.s_.L_.j 18 stks i 232 psi 20stks j 235 psi 22 stks J 236 psi ~ .................... · .................... '{- .................... .......................... _2_.4...s..t.k_.s. .... ,L_.___2__4..~_._p.s.!...j CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE .................... i ...... b--~T~; ..... i ....... ~'~,~] ...... 'i,, .................... ~ .................... t ................... 4 i 4 stks i 125 psi .................... i ..... -g~i-~ ..... i ..... ~-~-6-'/,'~T---] .................... i .... -~-a-~ .... i ..... ,i.~'~'-/,';¥-"i i 20stks j 800 psi J 28stks i 1,100 psi i i 32stks i 1,275 psi ! ..................... i .... -~'~ii~i; .... i'"'i;~.~iF~;~-i--i ..................... i .... .4_.0._.s__tk__s_ .... L__j_,_6_.2_.5___p__s_Lj i 44stks i 1,825 psi .................... f .................... i .................... -I ..................... i .... -4-A-s--t.k--s- .... .L--2--,-°-.2--5---P--S-Lj 26stks i 245 psi i .................................................................................... , 28stks i 247 psi i i 56stks i 2,400 psi ! i ......................... .... T .... r .................... i .... .... [ .................... i .... .... .... i .................... j .................... ~ .... '~'4'~:t-~ .... i .... f,'g,i-'/,-&-i---'i i .................... i .... 'Eg~i-~i; .... i'-'5;i:i~-f;~;i--i "' .................... i .................... ":- .................... i :- .................... t .................... ~ .................... '"t i .................... ~ .................... -i- .................... i i .................... i SHUT IN TIME J i 0.0 men i i [ .... -~E~fF,' .... ! .................... i .................... 'i,, !SHUT IN TIME! SHUT IN PRESSURE [ .... '~-~f~- ....i .................... i .................... 1 ¢i' [ '~:'~"aTh' ! .... .... .................... i .... ~x'~'~ j [Zi~iE~EiZ[ZiiiZZiZ]ZZiZZiZZj ..... ,,, [ "~-'r~ih- i .... .... .................... i ~'~'~"l~'~-i' l .... .... i 5.0mEn i ! [ .................... ~ .................... ~ ..................... J [ .................... J .................... 4 .................... 4 i 3.0mEn i [ 144 psi i [ 7.0mEn i 5.0mEn i i 135psi ! i 9.0mEn ..... '~:'~",~i~' ......................... T .... ~'.~'~"/,'~T'-'I .... "i'EE~i',:,'---1 .................... ..... 'E'6-'r~i~- ......................... T .... ?~,'~-'/,'~T .... [ .... -~EE~B'"'i .................... i .................... ..... '~".~",f,i~- ......................... T .... "i'~'~"~'~;-i----] .... '~EE[-;.;iF,'"'i .................... i .................... i .......................................... ~ ........................ -~E~-~---i .................... i .................... i 10.0 mEn i 124 psi NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Novcmber 9, 1998 Graham L. Alvord Kuparuk Drilling Tcam Leader ARCO Alaska. Inc. PO Box 100360 Anchorage, AK 99510-0360 Re~ Kuparuk River Unit 1 C- 17 ARCO Alaska, Inc. Permit No: 98-224 Sur Loc: 1395'FNL. 563'FWL. SEC 12. T11N. R10E. UM Btmhole Loc. 55'FSL, 1768'FWL. SEC 35. T12N. RIOE. UM Dcar Mr. Alvord: Enclosed is the approvcd application for permit to drill the above refcrcnccd well. Annular disposal has not bccn rcqucstcd as part of thc Permit to Drill application for Kuparuk Rivcr Unit Well No. lC-17. Please note that an5' disposal of fluids gcneratcd from this drilling operation which arc pumpcd down thc surface/production casing annulus of a well approved for am~ular disposal on Drill Site lC must comply with the rcquircments and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35.000 barrels through thc annular space of a single well or to usc that well for disposal purposes for a pcriod longcr than one .,,,ear. Thc permit to drill docs not exempt you from obtaining additional pcrmits required by law from other governmental agcncics? and docs not authorize conducting drilling operations until all other required permitting dctcrminations arc made. Blowout prcvcntion cquipmcnt (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a rcprescntative of the Comlnission to witness a test of BOPE installed prior to drilling new hole. Notice max' be given bx' contacting thc Commission pctrolcum_ field inspector on the North Slope pager at 659-3607. Chairman ~~) -- BY ORDER OF TIdE COMMISSION ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 26, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Cancellation of Approved Permit to Drill for 1C-17 Dear Mr. Commissioner: This is to inform you of our intentions to cancel the approved Permit to Drill for the 1C-17 Kuparuk well in the Kuparuk River Unit. The permit number is 98-57, API #50-029-22872. Sincerely, G. L. Alvord Kuparuk Drilling Team Leader Kuparuk Development GLA/skad STATE OF ALASKA ALASI~A OIL AND GAS CONSERVATION COMM-TSSION PERMIT TO DRILL 20 AAC 25.OO5 la. Type of Work Drill X Redrill r"] 1 lb Type of Well Exploratory E Stratigraphic Test r-'] Development Oil I · Re-Entry F: Deepen ~l I Service X Development Gas [~ Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 61' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25638, ALK 463 -' 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1395' FNL, 563' FWL, Sec. 12, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 36' FNL, 1821' FWL, Sec. 2, T11 N, R10E, UM 1Co17 #U-630610 At total depth 9. Approximate spud date Amount 55' FSL, 1768' FWL, Sec. 35, T12N, R10E, UM 11/9/98 $200,000 12. Distance to nearest I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) properly lineI 1C-09 10912' MD 36' @ Target feet 13.5' @ 475' feet 2560 6727' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 250' feet Maximum hole angle 61.13° Maximum surface 2453 psig At total depth (TVD) 3182 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +_200 CF 12.25" 9.625" 40.0# L-80 BTC 7505' 41' 41' 7546' 4379' 997 Sx Arcticset III L & 688 Sx Class G 8.5" 7" 26.0# L-80 BTC MOE 10462' 41' 41' 10503' 6343' 208 sx Class G 6.125" 4.5" 12.6# L-80 NSTC 609' 10303' 6156' 10912' 6727' 97 Sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations· Present well condition summary Total depth: tr%eeaSv~filcdal ff~;tt Plugs (measured) 0 RI G II~ A L Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measure~_d~ep~ True Vertical depth Structural ~ ~ .~:' Conductor crC I :ED Surface Intermediate ?'~' ~'~ ~'-' 1998 Production %/..¢: ~ ~ Liner - ' Perforation depth: measured Oil & 0as Co,is. 00B ission true vertical Anchorage 20. Attachments Filing fee X Property plat FI BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot F~ Refraction analysis FI Seabed report ~ 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ///~,,~.,/_.~ ~ (.,,~(, Title Kuparuk Drilling Team Leader Date ./' - Commission UseOnly Permit Nu~e~ .%~.. ~ c// I APl nu,~.,O.~ 50-' -- '~. "~ '~ 7 ;~)-.. I Approval date I i_fi~(~' [ See cover letter fOrother requirements Conditions of approval Samples required E~ Yes ~ No Mud logrequired E~r Yes [~ No Hydrogen sulfidemeasures ~' Yes E~ No Directional surveyrequired ,~t Yes ~ No Required working pressure for BOPE 2M F'~ 3M FI/~M.,,~[~,~ 10M Ei 15M Other: Original Approved by David W, Johnstor, by order of /[ _~ _C.)~ Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate STATE OF ALASKA ALAS'~A OIL AND GAS CONSERVATION COMM~%ION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of Work Drill X Redrill E~J lb Type of Well Exploratory F'~ Stratigraphic Test ~ Development Oil EJ Re-Entry r-i Deepen El service X Development Gas ~ Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 61' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25638, ALK 463 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1395' FNL, 563' FWL, Sec. 12, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 36' FNL, 1821' FWL, Sec. 2, T11N, R10E, UM lC-17 #U-630610 At total depth 9. Approximate spud date Amount 55' FSL, 1768' FWL, Sec. 35, T12N, R10E, UM 11/9/98 $200,000 12. Distance to nearest I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property lineI 1C-09 10912' MD 36' @ Target feet 13.5' @ 475' feet 2560 6727' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 250' feet Maximum hole angle 61.13° Maximum sudace 2453 psig At total depth (TVD) 3182 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole I Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24"I 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +_200 CF 12.25" 9.625" 40.0# L-80 BTC 7505' 41' 41' 7546' 4379' 997 Sx Arcticset III L & ,, 688 Sx Class G 8.5" 7" 26.0# L-80 BTC MOE 10462' 41' 41' 10503' 6343' 208 sx Class G 6.125" 4.5" 12.6# L-80 NSTC 609' 10303' 6156' 10912' 6727' 97 Sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vedical feet Casing Length Size Cemented Measured depth True Vertical depth Structural .i~ ~ ~ .~ ,: . Sudace Intermediate Production .~--. ¢~" . , Liner ~ ~!i ~ '-'- ~; ..'-~ Federation depth: measured 20. Attachments Filing fee X Property plat [~ BOP Sketch X Diverter Sketch X ' -¢'u~!ji''g program X Drilling fluid program X Time vs depth plot F~ Refraction analysis [-'; Seabed report F' 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~,¢¢,,/_~ ~ ~,~ Title Kuparuk Drilling Team Leader Date ~" Commission Use Only Permit Number ~"'! APl number I ^pprova, date lo ~,~q~ See cover letter tot OL,,~ - ~ 50- ~q - ~'~'~,, t ~ other requirements C0nditions of approval Samples required Fi Yes ~ No Mud g required Fi! Yes ~L No Hydrogen sulfide measures [~, Yes Fl No Directional survey required ~ Yes ~ No Required work~ng pressure for BOP[' [--,' ~M D 3M E', ~.~1-~ ~OM D I~M Other: Original Signed By ~avidW, ' ' _ Approved b~ Commissioner the commission Date . Form 10-401 Rev. 7-24-89 t in triplicate ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor Oct 22, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re," Application for Permit to Drill 1C-17 Kuparuk Development Injection Well, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the Kuparuk interval from 1C pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and further develop the production potential of the Kuparuk sands in the vicinity of 1C pad. The well is designated as a conventional injection well using a 9 5/8" surface casing string, a 7" intermediate casing string, a 4 Y2" liner and 3-1/2" tubing. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b) 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. Please note that the anticipated spud date for this well is November 9, 1998. If you have any questions or require further information, please contact Scott Goldberg at (907) 263-4622 or Chip Alvord at (907) 265-6120. Sincerely, Scott Goldberg Operations Drilling Engineer CC: Kuparuk I C-17 Well File Chip Alvord ATO-1200 MJ Loveland NSK6 Drill and Case Plan for 1C-17 Kuparuk Iniector General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 120' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. o Spud and directionally drill 12 1/4" hole to the surface casing point at 7546' MD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. , · Run and cement 9 5/8" 40# L80 BTC casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface in a one stage job. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. · TAM Port Collar will be placed in the casing string at 1000' MD to be used in the event that cement does not reach the surface in the primary one stage job. 6. Nipple down diverter, nipple up BOP's. Test BOP's. Notify AOGCC 24 hours before test , Make up 8 ¥2" bit and BHA an~r and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town o Drill float equipment and approximately 20' of new hole · Perform LOT · Record results and fax to town o Drill 8 1/2" hole to intermediate casing point at +10,503' MD · Perform a second LOT and determine an acceptable kick tolerance · If kick tolerance is acceptable, 8 ¥2" hole will be drilled to TD · If kick tolerance is unacceptable, 7" casing will be run to top Kuparuk 10. Run and cement 7" 26# L80 BTC-Mod Steps 11-14 are only applicable if we are required to top set the Kuparuk with 7" casing 11. Make up 6 1/8" bit and BHA and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 12. Drill float equipment and approximately 20' of new hole · Perform LOT · Record results and fax to town 13. Drill 6 1/8" hole to TD at 12,091' · Condition hole and mud for casing 14. Run and cement 4 Y2" 12.6# L80 NSTC Liner 15. Make a cleanout run with bit and scrapers · Displace to filtered seawater · Pressure test well to 3000 psi for 30 minutes · Record results and fax to town 1 C-17 Page 1 SG,10/22/98,vl 16. Run and land 3 Y2" tubing with gas lift completion 17. Nipple down BOP's. Install production tree and pressure test same. 18. Secure well, release rig 1 C-17 Page 2 SG,10/22/98,vl DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS Kuparuk I C-17 Injector Drilling Fluid Type Surface Hole: Intermediate Hole: Production Hole: Extended Bentonite Slurry Low Solids Non-Dispersed System Low Solids Non-Dispersed System Drillinq Fluid Properties: Formation Density FV YP ppg sec/qt lb/100 ft2 PV cP Filtrate mi/30 min Permafrost 8.9 120-140 25-40 16-20 12-15 West Sak 9.5-9.8 50-80 15-25 20-26 7-8 Colville 8.8-9.0 35-40 5-8 4-8 8-15 HRZ 9.5 40-50 8-20 15-25 5-6 Kalubik 9.5 40-50 8-20 15-25 5-6 Kuparuk C Sands 9.8-10.0 50-60 (Tau 0) 7-9 20-30 12.0 Drilling Fluid System: Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps MASP (Maximum Anticipated Surface Pressure); Based on estimated Static Bottom Hole Pressure data from nearby wells, expected reservoir pressures in the Kuparuk sands in the lC pad area are approximately 9.2 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.7 ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 6481'. Calculating MASP based on the most recent reservoir pressure data from nearby wells, and assuming a gas gradient of 0.11 psi/ft from the Kuparuk base to surface, the following MASP can be computed: MASP = (6629 ft)(0.48 - 0.11 psi/E) = 2453 psi 1 C-17 Page 1 SG,10/22/98,v.1 Drilling Area Risks: Drilling risks in the 1C-17 area are lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Borehole instabilty will be addressed through mud treatments and control drilling if necessary. Well Proximity Risks: The nearest existing well to lC-17 is 1C-09. As designed, the minimum distance between the two wells would be 13.5' at 475' MD. Annular Pumping Activities: Incident~tl fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of a annular disposal permitted existing well on DS-lC. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 1C-17 well will be freeze protected after running the 3 1/2" tubing and prior to the drilling rig moving off of the well. C,~J~(~ I~ '~£ .(,,~A,¢,~,=..¢ .,-~~--~. 1 C-17 Page 2 SG,10/22/98,v.1 TAM International Port Collar set at +/-1000' MD Surface csg. 9 5/8" 40# L-80 BTC (+/-7546' MD / 4379' TVD) ._ ,,RU 1C-17 Injector Completi¢,, _ 6-1/8" Hole / 4-1/2" Liner I. 3-1/2" 5M FMC Gert IV tubing hanger with 3-1/2" L-80 EUE 8RD-Mod pin down H. 3-1/2" 9.3# L-80 EUE 8RD-Mod tubing to surface G. 3-1/2" Camco DS Nipple w/2.812 No Go Profile, EUE 8RD-Mod, 3-1/2" x 6' pups installed above & below, EUE 8RD-Mod. F. 3-1/2" 9.3# L-80 EUE 8RD-Mod tubing to nipple All depths reference Parker 245 RKB E. 3-1/2" x 1-1/2" Camco 'MMM' mandrel w/DV & RK latch, 3-1/2" x 6' pups installed, L-80 EUE 8RD-Mod D. 1 jt 3-1/2" L-80 EUE 8RD-Mod tubing C. 3-1/2" Camco "D" landing nipple w/2.75" ID, NoGo profile, EUE 8RD-Mod 4-1/2" Liner Top: 200' above 7" shoe (+/- 10303' MD / 6156' TVD) Intermediate csg. 7" 26# L-80 BTC-Mod set above KUP, run to surface (+/- 10503' MD / 6343' TVD) B. I jt 3-1/2" L-80 EUE 8RD-Mod tubing A. Baker 3-1/2" 'GBH-22' Seal Assembly w/10' of seals and special Iocator to locate in liner tieback sleeve. Locator 5.125" OD, seals 4.0" ID. 6' handling pup installed on top 3-1/2" Liner Assembly (run on drillpipe): -- Baker 'C-2' tieback sleeve with Iocator, 6' -- Baker 5" x 7" 'ZXP' Liner Top Isolation Packer -- Baker 5" x 7" 'HMC' Hydraulic Liner Hanger -- Baker '80-40' 10' Seal Bore Extension (4.0" ID seal bore), 4-1/2" NSCT pin down Future Perforations Liner 4-1/2" 12.6# L-80 NSCT (+/- 10912' MD / 6727' 'I-VD) 4-1/2" NSCT landing collar/FS/FC SG, 10/22/98, v. 1 For: GOLDBERG I : I i$ 17 V4r~on ~4. A , CO Alaska, Structure : Pod lC Well : 17 I I Field : Kupcruk River Unit Locofion : North Slope, Alosko J <- West (feet) 4500 4000 3500 3000 2500 2000 ! 500 i 000 5~0 0 L. I I I I I , , + I ' ' , ~- 7oco /"--'"%TD 5 1/2 Liner TO LOCATION: / ,~"~,_ 'ITARGEi'- Top Kuporuk 55' FSL, 1768' FWL \ ~,'.,~, )End Anole Oroc- 7 Cosing Pt [ sec. 35, *~2N, ~0E I %._5$/c3o ' ' X, cso ~ ~ ~OOG Be ,n An le Ore ~ g' g P ~00 7r62 (TO TARGETI ~ I 56" FNL, 1821' ~L I % / ISEC. 2, T~ ~N. ~,0E I % h ~ooo DEP~762 ~ WS 10 ~ 4500 NORTH 6659 % , RKB ELEVATION: 102' WEST ~22 - % 0 / ~Tcp Wes( Sck Sends / I 9 14 BEGIN TURN TO TARO~ ~D=474 TMD=475 DEP=} ~ ..~':;- ~. 7..~ 1000 k 2722 DLS: 4.00 deg per 100 ft X~ ; "* :; 4 · ,~ , ~soo ~-50.39 ~ h,mhnr,r¢,:, k 2500 58 25 ' ~5~. EOC W0=1689 TMD:1973 DEP=752 ~ ' ~B/ PERMAFROST ~D=1802 TMD:2208 DEP:957 % 2000 2000 2500 ~ MAXIMUM ANGLE / ' ' ~oc T/ W 5AK SNO5 W0=3787 TMD=6319 OEP=4557 ~ 4000 ~ Begin Turn to Torget ~ p 0 WSlO ~D=4179 TMD=7131 DEP=5268~ 250 C~O0 ~D=4282 TMD=T545 DEP=5~55 ~ 9 5/8" CSG PT ~0=4~79 TM0=7546 DEP=56JO~~ L500 4500 c8o ~D=4659 TMD=8084 DEP=6102~ BEGIN ANGLE DROP ~D=4814 TMD=8447 DEP=8419~ 6006 ~-'~6.06 DLS: 2.00 de9 per 100 ft 5000 ~ 52.06 ~~8.o6 ~ 40.06 5500 C40 ~0=5662 TMD=97~EP=7~70 ~ 56.06 C50 ~D=6055 TMD=101¢8 DEP=7604 % 5206 C20 ~D=6199 TM~~E~7671 % ' B/ HRZ ~D=6221 TMD=10572 DEP=7680 ~ 28.06 6000 K-1 MARKER ~D=6525 TMD=10484 ~P=7721 % 2406 END ANGLE DROP - 7" CSG PT ~D=65~ TMD=10505 DEP=7728 ~- ' ~oo TAHOET ANGLE rAHOET - T/~UPAHU[ ~V~=6~3? r~D=Z~~=?V62~ TD - CSG PT TVD=6727 TMD=togt2 DEP=7888 7000 , I I I I I I I I I I , I I I I I I I I I I II I I I I I I I I I I I 0 500 1000 1500 2000 2500 5000 ~500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 VerHcml Section (feel) -> Azimuth 328.80 with reference 0.00 N, 0.00 E from slot #17 ~ o,e.,, ~ ,;~,~ For: GOLDBERG Ceo~c;notes ere in feet ~efetence ~ot ~17. Ve~lic¢l ~e~t~s are rele,ence ~8 (Pcrke~ 12~3). I~EQ A'dCO Alaska, Structure : Pod lC Well : Field : Kuperul< River Unit Locotion : North Slope, Alcsk <- West (feet) :~60 520 480 440 400 360 320 280 240 200 160 120 80 40 720 , I I I I I I I I I I I I I I I I I I I 680 640 600 560 520 480 440 4C0 I 360 ,~- 320 "~ 280 O 240 2C0 160 120 80 40 0 40 0 I I I I t I I I I I . '~, 1 600 ',, ',, ,, 500 · ~...~ 600 ',,,,,, ~.-..~24oo '% "~ 1300 · 40 80 i 720 1200 · %·% % 1100 640 60O 560 520 440 4C0 360 320 28O ~ I~ 240 ~.-..~00 ',~, 1000 5200 ~ _r-~7,,j -~ 900 50~ 800 '~ 3-~0 3900 ---....,oo 40 ', ,, , , , I 80 40 0 40 80 i i i i i i i i i i i i i i i i i/ i i i/ i/ i 560 520 480 440 ~oo 360 320 280 240 200 ~ 60 ~ 20 80 <-- West (feet) Z 0 I.A- CO Alaska, Inet1 Structure : Pad 1C Well : 17 ield : Kuparuk River Unit Locatian : Narth Slope. AlaskaI <- Wesf (feet) 4200 4000 3800 3600 3400 3200 3000 2800 A 2600 I '~- 2400 2200 Z 2000 1800 1600 1400 1200 1000 800 600 400 3400 3200 3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 ~ 4200 ~, 5500 '~,3900 900 ', 4000 '\ " 5300 · , 13700 3800 '~ 3700 " 5100 \"\ 3600 , ', \, 0 "~ 3500 4900 ,\ 3400 ',\ 4700 3300 3200 '\ 33OO \, · , 3000 · 4500 '~ 3100 ~800 ', 4300 \ , 4100 L 2800 · '~ 2900 \ 3900 240C " 3700 " 2200 ', 3500 " 2000 '~ 2500 3300 1800 '"" 3100 00 ~,,, 300 2900~ ",,, 1600 "'\ ~( 1400 · ~ '",, 2700 "'~ 2100 ~200 \, 800 '"'"',.,,1700 000 400 I I I I I [ I I I I i [ i I i I I I t 3400 3200 3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 <- West (feet) A 4CO Alaska, Inc t I Structure : Pad 1C Well : 17 J I Field : Kuparuk River Unit Location ; North 5lope, Alaska WELL PROFILE DATA ..... Pc. et ..... ~o lac o4~ ~ N~'~h£~=t v. Sect ~. ~ o.~ o,~ o.oo o.oo o.~ o.~ o.~ ~op 2~.~ o.~ 2~.oo25o.0oo.~ o.~ o.~ o~ Ee~in Turn ~o T~r~ '7~.~ g.~ ~.O0 ~74.08-6.03-~6.57 3.43 ~.~ E,d ~1 ~l~u,n1973.31 61.13329.8~ 16B8.53 5~5.1g -~.1~ 751.6~ ~.~ End of ~d 8~6.6g 61.13329.8~ ~14.12547~.31 -~.01 64tg.46 0.~ Eh= or ~oe~um10503.1~20.~ 32g.8~ {343.03 6~g.10 -~5.28 7728.03 2.~ T~{~ 1C--17 C~v Inj 1~3.1~ 20.~ 32g.85 {437.00 6~38.67 -~22.467)62.22 T.O. & [n~ of H~d l~t 1.7~20.~ 32g.8~ 6727.~672g.95 -~75.477867.76 0.~ 320 TRUE NORTH 350 0 10 340 20 330 30 310 c,,~,., =y ..o~ For: GOLDBERG O~e ~lc~ed : t6-Oct-~8 Plct Reference 1~ 17 Ve~='on [4. ~crd~note~ crc ;n feet r~er~ce s~t ~17. ]T~e Ve~icol Oe~tn~ ct. ref~e.ce RK8 (Perker 9OO 4O 7OO 7O{2 3( 60 290 70 280 ~ '" 80 3O 270 0 18,0 2 I 90 260 100 250 110 240 120 230 1 220 140 210 150 200 160 190 180 170 Normal Plane Travelling Cylinder - Feet All depths shown (]re Measured depths on Reference Wel ARCO Alaska, Inc. Pad 1C 17 slot #17 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE REPORT INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 17 Version #4 Our ref = prop2751 License : Date printed = 16-0ct-98 Date created : 6-Feb-98 Last revised = 16-Oct-98 Aia~k~ Oil a ~as Cous. Commission, A~chorag~ Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on nT0 19 45.173,w149 30 19.124 Slot location is nT0 19 31.453,w149 30 2.691 Slot Grid coordinates are N 5968837.883, E 561567.906 Slot local coordinates are 1395.00 S 563.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Proximities will incorporate elllpses - when survey tools are defined for both wells. Ellipse separation in reverse brackets, e.g. )10.2(, where available. Object wellpath MSS <0-7000'>,,gGI,Pad 1C PMSS <0-8677'>,,13,Pad 1C GMS <0-7615'>,,2,Pad 1C GMS <0-7753'>,,5,Pad 1C PMSS <0-10980'>,,14,Pad 1C PMSS <0-17089'>,,12,Pad 1C PMSS <0-11300'>,,11,Pad 1C GMS <0-9784'>,,7,Pad 1C GMS <0-9600'>,,8,Pad 1C GMS <0-7780'>,,1,Pad 1C PGMS ¢0-9002'>,,10GI,Pad 1C GMS <0-9700'>,,3,Pad 1C GMS <0-7575'>,,4,Pad 1C MMS <6948-7570'>,,WS#24,Pad 1C GMS <0-10243'>,,6,Pad 1C Closest approach with 3-D Last revised Distance 2-Jan-98 )13.5( 17-Feb-98 5-Aug-92 5-Aug-92 18-Mar-98 7-Jan-98 19-Mar-97 5-Aug-92 5-Aug-92 5-Aug-92 S-Aug-92 5-Aug-92 5-Au~-92 17-Dec-97 5-Au~-92 )321.5( 743.8( 405.5( 600.3( 181.6( 184.3( 218.3( 180.6( 861.5( 133.0( 628.5( 515.4( )11218.6 }302.2( Minimum Distance method M.D. Diver~ing from M.D. 475.0 475.0 100.0 100.0 270.0 270.0 260.0 260.0 100.0 10900.0 250.0 10520.0 250.0 10412.0 260.0 10678.7 260.0 5420.0 270.0 270.0 260.0 260.0 270.0 9274.4 260.0 260.0 1909.2 2020.0 260.0 9662.5 .o .. I KUPARUK RIVER L 'T · 20" DIVERTER SCHEMATIC 6 4 1 5 DO NOT SHUT IN DIVERTER .'AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES, "1, 2. MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVEN3T=R WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WEI ! RORE FLUIDS (DR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION, ARCO ALASKA, INC.. REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC2.5.035(b) , 2. 3. 4. 5. . 16' CONDUCTOR. SLIP~DN WELD STARTING HEAD. DIVERTER ASSEMBLY WITH ONE 2-1/16'- 2000 PSI BALL VALVE. 20' - 2000 PS! DRILLING SPOOL WITH ONE 16' OUTLET, ONE 16' HCR KNIFE VALVE WITH 16' DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPT]MUM DISPERSION IN PREVAILING WIND CONDITIONS. 20'- 2000 PSI ANNULAR PREVENTER. DKP 11~94 e 7 1 5 4 13 1. 16'- 2000 PSI STARTING HEAD 2. 11' - 3000 PSI CASING HEAD 3. 11' - 3000 PSI X 1:~5/8' - 5000 PSI SPACER SPOOL 4. 13-5/8' - 5000 PSI VARIABLE PIPE RAMS 5. 13-5/8' - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8' - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP. BLIND RAMS ON BTM 7. 13-5~' - 5000 PSI ANNULAR 5/8" 5000 PSI BOP STACK A(;;(~,t,) MULATOR CAPACITY CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. - OESERVE TIME. THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLCSED WITH CHARGING PUMP OFF. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. ?- CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 FSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED 30 ZERO FSI. TEST ANNULAR PREVENTOR TO 3000 PSI ONLY. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE lINES. 7. 7EST TO 250 PS! AND 5000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES. LINES. AND CHOKES WITH A 250 PSI LOW AND 5000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAM~S AND CLCSE Bo3-rOM PIPE RAMS. TEST BOttOM RAMS TO 250 PSI AND 5000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. F, ACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. ©FEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STAND?IPE VALVES TO 5000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE EOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. NOTE: PRIOR TO DRILLING OUT OF THE INTERMEDIATE CASING SHOE ALL FLANGES AND SEALS BROKEN BETWEEN THIS TEST AND THE PRIOR ONE WILL BE TESTED TO 250 PSI LOW AND 5000 PSI HIGH ARCO Alaska, Inc. "¢ Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor Oct 22, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill lC-17 Kuparuk Development Injection Well, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the Kuparuk interval from 1C pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and further develop the production potential of the Kuparuk sands in the vicinity of 1C pad. The well is designated as a conventional injection well using a 9 5/8" surface casing string, a 7" intermediate casing string, a 4 Y2" liner and 3-1/2" tubing. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1 ) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b) 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) Aisc note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on ,~" the rigs as is the standard operating procedure in the Kuparuk River Unit drilling:O~e~tiOn~ :i. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type Icg generation and sample catching are planned. Please note that the anticipated spud date for this well is November 9, 1998. If you have any questions or require further information, please contact Scott Goldberg at (907) 263-4622 or Chip AIvord at (907) 265-6120. Sincere!y, Scott Goldberg Operations Drilling Engineer CO: Kuparuk 1 C-17 Well File Chip Alvord ATO-1200 MJ Loveland NSK6 Drill and Case Plan for 1C-17 Kuparuk Iniector General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 120' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. . Spud and directionally drill 12 1/4" hole to the surface casing point at 7546' MD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. Run and cement 9 5/8" 40# L80 BTC casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface in a one stage job. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. · TAM Port Collar will be placed in the casing string at 1000' MD to be used in the event that cement does not reach the surface in the primary one stage job. 6. Nipple down diverter, nipple up BOP's. Test BOP's. Notify AOGCC 24 hours before test . Make up 8 1/2" bit and BHA and ~F~-e~e-eellar and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town . Drill float equipment and approximately 20' of new hole · Perform LOT · Record results and fax to town Drill 8 Y2" hole to intermediate casing point at +10,503' MD · Perform a second LOT and determine an acceptable kick tolerance · If kick tolerance is acceptable, 8 Y2" hole will be drilled to TD · If kick tolerance is unacceptable, 7" casing will be run to top Kuparuk 10. Run and cement 7" 26# L80 BTC-Mod Steps 11-14 are only applicable if we are required to top set the Kuparuk with 7" casing 11. Make up 6 1/8" bit and BHA and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 12. Drill float equipment and approximately 20' of new hole · Perform LOT · Record results and fax to town 13. Drill 6 1/8" hole to TD at 12,091' · Condition hole and mud for casing 14. Run and cement 4 Y2" 12.6# L80 NSTC Liner 15. Make a cleanout run with bit and scrapers · Displace to filtered seawater · Pressure test well to 3000 psi for 30 minutes · Record results and fax to town 1 C-17 Page 1 SG,10/22/98,vl 16. Run and land 3 Y2" tubing with gas lift completion 17. Nipple down BOP's. Install production tree and pressure test same. 18. Secure well, release rig 1 C-17 Page 2 SG,10/22/98,vl DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS Kuparuk I C-17 Injector Drillinq Fluid Type Surface Hole: Intermediate Hole: Production Hole: Extended Bentonite Slurry Low Solids Non-Dispersed System Low Solids Non-Dispersed System Drilling Fluid Properties: Formation Density FV YP ppg sec/qt lb/100 ft2 PV cP Filtrate mi/30 min Permafrost 8.9 120-140 25-40 16-20 12-15 West Sak 9.5-9.8 50-80 15-25 20-26 7-8 Colville 8.8-9.0 35-40 5-8 4-8 8-15 H RZ 9.5 40-50 8-20 15-25 5-6 Kalubik 9.5 40-50 8-20 15-25 5-6 Kuparuk C Sands 9.8-10.0 50-60 (Tau 0) 7-9 20-30 12.0 Drilling Fluid System: Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps MASP (Maximum Anticipated Surface Pressure): Based on estimated Static Bottom Hole Pressure data from nearby wells, expected reservoir pressures in the Kuparuk sands in the 1C pad area are approximately 9.2 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.7 ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 6481'. Calculating MASP based on the most recent reservoir pressure data from nearby wells, and assuming a gas gradient of 0.11 psi/ft from the Kuparuk base to surface, the following MASP can be computed: MASP = (6629 ft)(0.48- 0.11 psi/ft) = 2453 psi 1 C-17 Page 1 SG,10/22/98,v.1 Drillinq Area Risks: Drilling risks in the lC-17 area are lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Borehole instabilty will be addressed through mud treatments and control drilling if necessary. Well Proximity Risks: The nearest existing well to lC-17 is lC-09. As designed, the minimum distance between the two wells would be 13.5' at 475' MD. Annular Pumping Activities: Incidental, tYuids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of a annular disposal permitted existing well on DS-lC. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The lC-17 well will be freeze protected after running the 3 Y2" tubing and prior to the drilling rig moving off of the well. [.~Or~.(C~ ~'--~ '~'O/" CZCt~¢...~[C.~ C/~{) C~O~(. 1 C'17 Page 2 SG,10/22/98,v. 1 TAM International Port Collar set at +/-1000' MD Surface csg. 9 5/8" 40# L-80 BTC (+/-7546' MD / 4379' TVD) 1C-17 Injector Completi ,, l 6-1/8" Hole / 4-1/2" Liner I. 3-1/2" 5M FMC Gen IV tubing hanger with 3-1/2" L-80 EUE 6RD-Mod pin down H. 3-1/2" 9.3# L-80 EUE 8RD-Mod tubing to surface G. 3-1/2" Camco DS Nipple w/2.812 No Go Profile, EUE 8RD-Mod, 3-1/2" x 6' pups installed above & below, EUE 8RD-Mod. F. 3-1/2" 9.3# L-80 EUE 8RD-Mod tubing to nipple All depths reference Parker 245 RKB E. 3-1/2" x 1-1/2" Camco 'MMM' mandrel w/DV & RK latch, 3-1/2" x 6' pups installed, L-80 EUE 8RD-Mod D. 1 jt 3-1/2" L-80 EUE 8RD-Mod tubing C. 3-1/2" Camco "D" landing nipple w/2.75" ID, NoGo profile, EUE 8RD-Mod 4-1/2" Liner Top: 200' above 7" shoe (+/- 10303' MD / 6156' TVD) Intermediate csg. 7" 26# L-80 BTC-Mod set above KUP, run to surface (+/- 10503' MD / 6343' TVD) B. 1 jt 3-1/2" L-80 EUE 8RD-Mod tubing A. Baker 3-1/2" 'GBH-22' Seal Assembly w/10' of seals and special Iocator to locate in liner tieback sleeve. Locator 5.125" OD, seals 4.0" ID. 6' handling pup installed on top 3-1/2" Liner Assembly (run on drillpipe}: -- Baker 'C-2' tieback sleeve with Iocator, 6' -- Baker 5" x 7" 'ZXP' Liner Top Isolation Packer -- Baker 5" x 7" 'HMC' Hydraulic Liner Hanger -- Baker '80-40' 10' Seal Bore Extension (4.0" ID seal bore), 4-1/2" NSCT pin down Future Perforations Liner 4-1/2" 12.6# L-80 NSCT (+/- 10912' MD / 6727' TVD) 4-1/2" NSCT landing collar/FS/FC SG, 10/22/98, v. 1 [ RCO Alaska, lnc--' / Slructure : Pod 10 Well : 17 [ by,~.~ For: GOLDBERG[ tF'Jeld : Kuparuk River Unit Location : North Slope, AlaskaJ Dote DN3tt~d : l~-Cc~-~ J ~ot Rete~e~ce il 17 V~on ~4. jT~:e Vertical Depths ~re tefecence RKO (Pcr~er ~2~5). ~ 4500 4000 3500 3000 2500 2000 ! 500 1000 5~0 0 70CO ~TD 5 1/2 Uner - ' TO LOCATION' / ~ ~TARGET To- Ku~aruk ' ' 55' ~SL 1768' ~WL J ~ ~ )End Ang~ g~o ~ 7 CasJna Pt [~ ~ (~ ~:..;. ~ :~. :" ~'= ~ ? J 328.79 AZIMUTH ~ ............. :,.. ,.~.~..,,., IIU~ ~tU L~USI) ~ .~;~qgi~0~.~; ~5500 **,Piene of Proposol*-* ff~RG~ LOCATION: I % C80 I Ge' FNL, 1821' PICL [ % ~J k L, .000 TARG~ ~ 5 8 Cas[n L TMD=10605 '% 0EP=7762 ~ WS1 0 4500 NORTH 6659 % ' ] WEST 4022 . RKB ELEVATION: 102' ~ ~4000 A 0 ~ ~Top Wes~ Sck Sends [ ~ KOP TVD=aS0 TMD=a50 9EP=0 ~ ~ ~.oo ~ h z 1000 --~27'22 OLS: 4.00 deg per 100 ft -- ~O0 ~50.39 2500 ~58.25 EOC ~D=1689 TMD=1973 OEP=752 ~ ] 3000 1000 ~s~ermofros~ 500 T/ W 5AK SND5 ~0=3787 TM0=6319 DEP=4557 4000- Beqin Turn ~o Tareet WSIO WD=4179 TMD=7131 DEP=5268 250 Az 1 Ci00 W0=4282 TM0=73~5 DEP=5¢55 9 5/8" CSG PT WD=4379 TMD=7546 DEP=5630 i 4500 2%~ u 500 C80 W0=4659 TMD=808~ OEP=6iO BEGIN ANGLE DROP WD=4814 TMD=8447 DEP=5~ig~ 8006 ~'~6.06 DLS: 2.00 de9 per i O0 ft 5000 ~ 52.06 48.o~ C~O ~D=53~O TMD~ D~=7094~ 44.06 55C0 ~ ~ 40.06 C~O W0=5662 TMD=9732 DEP=7370 ~ 58.06 C50 ~¢D=6055 TMD=~8 DEP=7604 ~ 3205 C20 WD=619~~8 DEP=7671 60C0 B/ HRZ WD=622~=10572 DEP=7680 % 28.06 K-1 MARKER WO=6~MD~8~EP=7721 END ANGLE DROP - 7" CSO PT WD=65z~05 ~728 ,~ .... ~o TARGET ANGLE TkROET - T/KUPARUK TVD=6437 T~[D=~O~EP=??6e ~ ~o.o~ 20 DEG r/c~ w~=fis~7 tMB~1o773 TD 7%¢~¢~ TVD:6?2? TMD:t0912 DE~=7868 7000 ] ~ ~ i ~ z , ~ r i ~ i , J ~ ~ ~ ~ ~ i ~ i ~ ~ ~ J , ~ ~ i , 0 500 1000 1500 2000 2500 5000 5500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 Vertical Section (feet) -> Azimuth 328.80 with reference 0.00 N, 0.00 E from slot #17 520 ~ 0 Z aLaCO Alaska, Inc-':i Structure : Pad 1C Well: 17 Field : Kuparuk River Unif Locafion : Norfh Slope, Alaska/ <- Wesf (feel) 560 520 480 440 400 360 520 250 240 200 160 120 80 40 2~c 1 t 2C0 '~, i 300 ., '" t '"'"'-~ 1 200 .. 120 ~ "', 720 i I I [ I I I I I I I t r I , I I I [ I I 680 i J · 6C0 "~, 1700 560 ', 520 ] '"'" 4 ' I ,, 48C ~ I ""'~., 1 600 440 ~1 ,, 4C0 ~ '", 36O -~ O0 '", ~ ~ '~ 1500 k,i 400~ " ~'~'~. 23 O0 -. 8O ¢0 I 600 1500 ! 40 80 i 720 I ? 6~0 ? 640 600 560 L 5'20 ;- 440 400 560 5 0 480 440 400 360 320 280 240 200 160 120 0 <- West (feet) A 1 [ Z I520 '-~ I -'--'"~o k o k 200 %. 1100 ' I '". ~ ~0 ,. '-x ~00 5200 ~ 5OO , ~ ~ I 80 40 80 O09 00/ 90~ ~ " ~ 006 ~ ~,, 0o0; -i ,90~7 %x,, '"' ~'~ ~ O0/_g 0069 X ~ "%, O0a ~ -4 OOf[ ',, OO9 ~ oog~ ",, · ~ 000~ ~ DO~ 0 Z I V OOgE OOO~ 00~¢ i ~ °°9~I , ' 099~ j 00~ oog~' 00/_~ OOLt~ 00C1~ oog~ 00&t 0061~ OOtg 00;~ % 00~'~ ~ 00/_'~ ~ o0[g ooggl ,, : ; , ~ i i i i i t i i i i t i i i i i i i i [ i i i 1 i , 0O~ OD~ ODD OOg 000~ 00Z[ 009t 009L O0~L 000~ 00~ 0O~Z 009~ O0~Z 000~ 00~ 009~ [D~lSDI¥ 'edoIS qUON : uO!ID~O-I ;lUll JeA!~{ anJDdn>{ : pIaL-{ : 009 OO9 O00L OOZ~ O0~L oogt 000~ Z 0 oo~g O0~g --,,- Ioo~~ V 0095 O00E -00~ ooyc 00g[ 0095 000~ OOg~ [- RC0 -] as a, J Structure: Pod I C Well: 17 Field : Kuparuk River Unit Location : North Slope, Alaska. WELL PROFILE DATA ..... ~t ..... ~o ~¢ O;r ~ ~o~ ~t v. ~ i~ ~ o.oo o,~ o~o o.~o o.co o.oo o.co o.~ I ~P 2~.co o.~ 2~.co2~o.~oo.co o.co O.~ j~e~n T~m :o r~r~t ~7~.00 ~.~ 2~.C0~1~,C8-6.03-16.57 3.4J ~.~ E~d cf ~:~rn 1975.516lA3 329.85 168a.~5 575. t9 -~1.17 751.6~ j[~d cf Orc~m 10503.1¢~0.~ 329.85 63¢3.05 6~.I0-~5,2~ 7728.0~ T~t IC-17 C~v ~.j lC603.1~20,~ 32g.85 6457.00 66~8.57 -~22.~67762.22 JT.O. · E~d of ~U4 I~g11.7520.~ 329.85 6727.00 672g.g5 -~75.~77867.76 0.~I 350 0 i0 540 20 33O 52O 3i0 i50 / 3O 290 280 270 510 2!0 i 260 3O 900 70O 7OO 6O 900 8O 9O 100 25O 1i0 240 120 230 220 210 2OO 190 Norrnof Plane Travelling Cylinder - Fee[ 140 150 180 170 160 All depths shown are Measured depths on Reference Well ARCO Alaska, Inc. Pad lC 17 slot #17 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE REPORT INCLUDING POSITION U~CERTAINTIES by Baker Hughes INTEQ Your ref : 17 Version Our ref : prop2751 License : Date printed : 16-0ct-98 Date created : 6-Feb-98 Last revised : 16-0ct-98 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is n70 19 31.453,w149 30 2.691 Slot Grid coordinates are N 5968837.883, E 561567.906 Slot local coordinates are 1395.00 S 563.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Proximities will incorporate ellipses - when survey tools are defined for both wells. Ellipse separation in reverse brackets, e.g. )10.2(, where available. Object wellpath MSS <0-7000'>,,gGI,Pad 1C PMSS <O-8677'>,,13,Pad 1C GMS <O-7615'>,,2,Pad 1C GMS <O-7753'>,,5,Pad 1C PMSS <0-10980'>,,14,Pad 1C PMSS <O-17089'>,,12,Pad 1C PMSS <0-11300'>,,11,Pad 1C GMS <O-9784'>,,7,Pad 1C GMS <0-9600'>,,8,Pad 1C GMS <0-7780'>,,1,Pad 1C PGMS <O-9002'>,,lOGI,Pad 1C GMS <O-9700'>,,3,Pad 1C GMS <O-7575'>,,4,Pad lC MMS <6948-7570'>,,WS#24,Pad 1C GMS <O-10243'>,,6,Pad lC Closest approach with 3-D Last revised Distance 2-Jan-98 )13.5{ 17-Feb-98 5-Aug-92 5-Aug-92 18-Mar-98 7-Jan-98 19-Mar-97 5-Aug-92 5 -Aug- 92 5 -Aug- 92 5 -Aug- 92 5-Aug-92 5-Aug-92 17-Dec-97 5-Aug-92 )321.5( )743.8( )405.5( )600.3( )181.6( )184 3( )218 3( )180 6( )861 5( )133 o( )628 5( )515 4( ) 11218.6 )302.2( Minimum Distance method 475.0 100.0 270.0 260.0 100.0 250.0 250 0 260 0 260 0 270 0 260 0 270 0 260.0 1909.2 260.0 Diverging from M.D. 475.0 100.0 270.0 260.0 10900.0 10520.0 10412.0 10678.7 5420.0 270.0 260.0 9274.4 260.0 2020.0 9662.5 ¢' KUPARUK RIVER L a' IT 20" DIVERTER SCHEMATIC I t DO NOT SHUT IN DIVERTER -'AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. , . MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS iMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WE[! RORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION, ARCO ALASKA, INC.. REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16' CONDUCTOR. :~,i~UJ~dCi~ 2. SLIP~DN WELD sTARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16'- 2000 PSI BALL VALVE 4. 20'- 2000 PS! DRILLING SPOOLWITH ONE 16' OUTLET. 5. ONE 16' HCR KNIFE VALVE WITH 16" DIVERTER LiNE THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20"- 2000 PSI ANNULAR PREVENTER. DKP 11/~94 7 ,6 , J 5 1. I3 I 13 1. 16' - ~ PS! STARTING HEAD 2, 11' - 3000 PSI CASING HEAD 3. 11' - 3000 PSI X 13-5/8' - 5000 PSI SPACER SPOOL 4. 13-5/8' - 5000 PSI VARIABLE PIPE RAMS 5. 13-5/8' - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8' - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP. BLIND RAMS ON BTM 7. 13-5,'B' - 5000 PSI ANNULAR 5/8" 5000 P-SI BOP STACK AC(;;t,JMULAT©R CAPACITY TEST CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. OBSERVE TIME. THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PS! AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. TEST ANNULAR PREVENTOR TO 3000 PS! ONLY. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE UNE VALVES. 6. CLOSE TOP PiPE RAMS AND HCR VALVES ON KILL AND CHOKE ENES. 7. TEST TO 250 PS! AND 5000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 5000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT 1S NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE Bo,-rOM PIPE RAMS. TEST Bo~roM RAMS TO 250 PSI AND 5000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 5000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. NOTE: PRIOR TO DRILLING OUT OF THE INTERMEDIATE CASING SHOE ALL FLANGES AND SEALS BROKEN BETWEEN THIS TEST AND THE PRIOR ONE WILL BE TESTED TO 250 PS! LOW AND 5000 PSI HIGH · WELL PERMIT CHECKLIST COMPANY ~ ~"[,,CO WELL NAME t G - } ~ PROGRAM: exp [] dev [] redrll [] serv ~(wellbore seg ~1 ann. disposal para req ~l .. ADMINISTRATION 1. Permit fee attached ....................... _N ~ 3 2. Lease number appropriate ................... · DATE 3. Unique well name and number .................. 4. Well located in a defined pool .................. ~ N 5. Well Iocaled proper distance from drilling unit boundary .... ,~ N '~' ~ 6. Well located proper distance from other wells .......... ~ N 7. Sufficient acreage available in drilling unit ............ ~ N 8. If deviated, is wellbore plat included ............... ~ N 9. Operator only affected party ................... (.~! N 10. Operator has appropriate bond in force ............. ~) N 11. Permit can be issued without conservation order ........ q~ N :~ 12. Permit can be issued without administrative approval ...... (3' N 13. Can permit be approved before 15-day wait ........... (~ N ENGINEERING APPR DATE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMl- vol adequate to circulate on conductor & surf csg ..... 17. CMl- vol adequate to tie-in long string to surf csg ........ Y N 18. cur will cover all known productive horizons .......... ~ N 19. Casing designs adequate for C, T, B & permafrost ....... ~ N 20. Adequate tankage or reserve pit ................. (.~ N 21. If a re-drill, has a r10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. ~,~ N 23. If diverter required, does it meet regulations .......... ~ N 24. Drilling fluid program schematic & equip list adequate ..... N 25. BOPEs, do they meet regulation ................ N 26. BOPE press rating appropriate; test to ~_~o~5~ psig. N 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H~S gas probable ................. GEOLOGY A~,~R DATE , 3Q Permit can be issued w/o hydrogen sulfide measures. :_.~.._~ .... Y N 31. Data presenled on potential overpressure zon~~ Y N 32. Seismic analysis of shallow g.a_szon.ezs::-: :' . . ' ........ Y N ~. 33. Seabed condition.su...rfr~y:(if:0ff:sl~'6~) ............. Y N 3~ogt_a¢~nam. e/~'6h,e ,for weekly progress reports ....... Y N __ ' .-lexp~oramry omy] ANNULAR DISPOSAL APPR DATE 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; wi~'~bt'impair..[~echanical integrity of the well used for disposal; Y N (c) (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circu, mv._e, nt 20 AAC 25,252 or 20 AAC 25.412. Y N UIC/Annular COMMISSION: GEOJ_~?Y: ENGINEER.lNG: JDH Comments/Instructions: Mcheklisl rev 05129198 ,rill ~,, ~m'~fl.',~wof('Jiml~dUll~;~\, hr, I. h',l Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Urc- I q2 --2-Li Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. August 13, 2005 7518 1 3.5" 9.3 lb. L-80 Tubing Well: 1 C-17 Field: Kuparuk State: Alaska API No.: 50-029-22872-00 Top Log IntvI1.: Surface Bot. Log IntvI1.: 10,318 Ft. (MD) Inspection Type: Corrosive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the liD" Nipple @ 10,277' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing with respect to corrosive and mechanical damages. The 3.5" tubing logged appears to be in good to poor condition with respect to corrosive damage. The caliper recordings indicate a hole in joint 259 (8,101 '). Wall penetrations in excess of 20% wall thickness are recorded in 226 of the 335 joints logged. The damage appears in the forms of general corrosion, isolated pitting, and lines of corrosion. A line of corrosive damage is recorded in the inteNal between joints 80 and 328 (2,500' -10,318'). No significant areas of cross-sectional wall loss or 1.0. restrictions are recorded throughout the tubing logged. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WAll PENETRATIONS: Hole Line of Pits Line of Corrosion Line of Corrosion Line of Corrosion (100%) ( 79%) ( 76%) ( 76%) ( 70%) Jt. Jt. Jt. Jt. Jt. 259 @ 239 @ 245 @ 265 @ 240 @ 8,101 Ft. (MD) 7,484 Ft. (MD) 7,664 Ft. (MD) 8,306 Ft. (MD) 7,520 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL lOSS: No significant areas of cross-sectional wall loss (> 11 %) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.0. restrictions are recorded throughout the tubing logged. (~' ," I' \f.'h'.~ Ie.: ~ ¡:.) L~,f~,6 \; :1 ~Ci ¡~";;,I:",,.I G)) (:;" I) r n ¡::: I~~,; 'i) ICJ ,-"".j I Field Engineer: L. Mills-Dawson Analyst: M. Tahtouh Witness: T. Senden I ProActive Diagnostic Services, lnc. I P.O. Box 13691 Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 clds,. Well: Field: Company: Coun try: 1 C-l 7 Kuparuk ConocoPhillips Alaska, Inc. USA I Tubing: Weight 9.3 ppf Nom.OD 3.5 ins Grade & Thread L-80 Penetration and Metal Loss (% wall) _ penetration body 400 IIæIJII metal loss body 300 200 100 o 0 ;;... ~to 1 % 10% 1 0 to 20 to 40 to ove r 20% 40% 85% 85% Number of joints analysed (total = 335) pene. 0 20 89 100 125 1 loss 11 322 2 0 0 0 Damage Configuration ( body) 250 200 1 SO 100 so o isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of joints damaged (total = 302) 55 24 222 0 PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: Nom.lD 2.992 ins August 13, 2005 MFC 24 No. 00387 1.69 24 M. Tahtouh Upper len. 1.2 ins Lower len. 1.2 ins Nom. Upset 3.5 ins Damage Profile (% wall) _ penetration body o o ~ metal loss body SO 100 Analysis Overview page 2 ;l PDS KEPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1 C-l 7 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal J.D.: 2.992 in Country: USA Survey Date: August 13, 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss I.D. Comments (% wall) (Ins.) (Ins.) 0/ (Ins.) 0 50 100 In .1 9 0 0.02 9 4 2.89 PUP 1 13 0 0.03 11 .2 2.89 Lt. Deposits. 1.1 46 0 0.03 13 7 2.92 PUP Shallow pitting. 1.2 48 0 0.03 13 7 2.91 PUP Shallow pitting. 2 51 0 0.04 15 .2 2.91 Shallow corrosion. Lt. Deposits. 3 85 0 0.03 11 .2 2.90 4 116 0 0.03 12 .2 2.90 5 147 0 0.04 16 .2 2.89 Shallow corrosion. Lt. Deposits. 6 178 0 0.03 11 2.90 7 209 0 0.03 10 .2 2.91 8 241 0 0.03 '13 .2 2.93 Shallow pitting. 9 271 0 0.03 13 2.91 Shallow pitting. 10 302 0 0.04 15 .2 2.90 Shallow corrosion. 11 333 0 0.03 10 2.91 Lt. Deposits. 12 364 0 0.04 14 .2 2.91 Shallow corrosion. 13 396 0 0.03 11 .2 2.90 Lt. Deposits. 14 427 0 0.04 14 2.90 Shallow corrosion. 15 459 0 0.03 13 .2 2.93 Shallow pitting. 15.1 490 0 0 0 0 2.81 DS Nipple 16 491 0 0.03 13 1 2.93 Shallow pitting. 17 521 0 0.03 11 .2 2.92 Lt. Deposits. 18 552 0 0.03 13 .2 2.94 Shallow corrosion. 19 583 0 0.03 12 2 2.92 20 615 0 0.03 10 2 2.90 21 646 0 0.02 9 .2 2.91 22 678 0 0.02 9 2.94 23 709 0 0.03 10 2.91 Lt. Deposits. 24 739 0 0.04 15 .2 2.93 Shallow corrosion. 25 771 0 0.03 10 2 2.94 26 802 0 0.03 10 .2 2.92 27 834 0 0.03 13 .2 2.92 Shallow pitting. Lt. Deposits. 28 865 0 0.03 11 2.92 29 896 0 0.03 12 .2 2.92 30 928 0 0.03 13 .2 2.93 Shallow pitting. 31 959 0 0.02 8 2 2.92 32 990 0 0.04 15 .2 2.93 Shallow corrosion. 33 1022 0 0.03 13 .2 2.92 Shallow pitting. 34 1053 0 0.03 10 .2 2.92 35 1082 0 0.02 9 .2 2.92 Lt. Deposits. 36 1114 0 0.05 19 1 2.92 Shallow pitting. 37 1145 0 0.04 14 .2 2.91 Shallow pitting. Lt. Deposits. 38 1175 0 0.03 10 .2 2.92 Lt. Deposits. 39 1207 0 0.03 11 2 2.91 Lt. Deposits. 40 1238 0 0.03 12 2 2.93 41 1270 0 0.02 9 .2 2.93 42 1301 0 0.03 10 2.89 43 1332 0 0.02 9 .2 2.93 44 1364 0 0.05 19 3 2.92 Shallow corrosion. 45 1395 0 0.02 9 2 2.91 46 1427 0 0.05 19 2.92 Shallow corrosion. I Penetration Body I',;::::: Metal Loss Body Page 1 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1 C-l 7 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal 1.0.: 2.992 in Country: USA Survey Date: August 13/ 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss 1.0. Comments (% wall) (Ins.) (Ins.) % (Ins.) 50 100 47 1457 0 0.02 7 .2 2.92 48 1488 0 0.04 14 .2 2.92 Shallow corrosion. 49 1516 0 0.05 21 .2 2.91 Corrosion. Lt. Deposits. 50 1546 0 0.03 13 .2 2.91 Shallow pitting. 51 1578 0 0.03 13 .2 2.92 Shallow pitting. 52 1609 0 0.04 15 .2 2.93 Shallow corrosion. 53 1640 0 0.04 17 .2 2.92 Shallow pitting. 54 1671 0 0.03 12 3 2.92 55 1702 0 0.04 17 .2 2.92 Shallow pitting. 56 1734 0 0.04 17 .2 2.91 Line of shallow pits. 57 1764 0 0.05 21 .2 2.91 Line of pits. 58 1794 0 0.06 23 .2 2.91 Line of pits. 59 1826 0 0.05 20 4 2.89 Line of shallow pits. 60 1856 0 0.04 18 .2 2.87 Shallow pitting. 61 1887 0 0.06 23 .3 2.91 Line of pits. 62 1919 0 0.04 17 4 2.93 Line of shallow pits. 63 1950 0 0.04 18 .3 2.89 Line of shallow pits. 64 1981 0 0.04 16 .3 2.91 Line of shallow pits. 65 2012 0 0.03 13 3 2.90 Shallow pitting. 66 2044 0 0.04 15 4 2.85 Shallow pitting. 67 2073 0 0.04 17 4 2.87 Shallow pitting. 68 2105 0 0.03 10 4 2.87 69 2137 0 0.05 20 .3 2.83 Shallow pitting. 70 2169 0 0.06 22 .3 2.82 Line of pits. 71 2201 0 0.07 28 4 2.80 Isolated pitting. 72 2232 0 0.05 19 4 2.80 Shallow pitting. 73 2264 0 0.06 25 .3 2.80 Isolated pitting. 74 2295 0 0.06 24 6 2.78 Isolated pitting. 75 2324 0 0.05 19 4 2.84 Shallow pitting. 76 2356 0 0.06 22 .3 2.86 Isolated pitting. 77 2386 0 0.05 20 .3 2.85 Shallow pitting. 78 2417 0 0.04 17 .3 2.82 Shallow pitting. Lt. Deposits. 79 2448 0 0.05 21 4 2.83 Isolated pitting. 80 2479 0 0.06 24 .3 2.86 Line of pits. 81 2510 0 0.06 22 4 2.88 Line of pits. 82 2542 0 0.06 24 .3 2.86 Line of pits. 83 2572 0 0.07 29 5 2.84 Line of pits. 84 2604 0 0.06 22 .3 2.81 Line of pits. Lt. Deposits. 85 2635 0 0.06 22 4 2.84 Line of pits. 86 2666 0 0.06 22 3 2.83 Line of pits. 87 2697 0 0.06 24 3 2.83 Line of pits. Lt. Deposits. 88 2728 0 0.08 30 4 2.84 Line of pits. 89 2759 0 0.07 26 4 2.85 Line of pits. 90 2790 0 0.04 17 3 2.83 Shallow pitting. 91 2822 0 0.03 10 .3 2.86 92 2853 0 0.06 22 .2 2.87 Isolated pitting. 93 2885 0 0.03 13 .3 2.91 Shallow pitting. 94 2916 0 0.05 19 .3 2.85 Shallow pitting. 95 2947 0 0.04 14 .3 2.83 Shallow pitting. 96 2979 0 0.06 25 .3 2.82 Line of pits. "Penetration Body l:}tl Metal Loss Body Page 2 ~ PDS KEPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1 C-l 7 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. NominaII.D.: 2.992 in Country: USA Survey Date: August 13, 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss I.D. Comments (% wall) (Ins.) (Ins.) o/C) (Ins.) 0 50 100 97 3008 0 0.06 22 3 2.81 Line of pits. 98 3039 0 0.05 20 -, 2.82 Line of pits. .:;¡ 99 3071 0 0.07 27 4 2.83 Line of pits. 100 3101 0 0.05 20 4 2.84 Isolated pitting. Lt. Deposits. 101 3133 0 0.05 20 4 2.87 Line of shallow pits. Lt. Deposits. 102 3165 0 0.04 17 6 2.83 Shallow corrosion. 103 3197 0 0.04 16 3 2.85 Shallow corrosion. Lt. Deposits. 104 3229 0 0.05 20 3 2.85 Line of pits. Lt. Deposits. 105 3259 0 0.05 20 3 2.87 Line of pits. Lt. Deposits. 106 3291 0 0.05 20 4 2.85 Line of pits. Lt. Deposits. 107 3323 0 0.07 26 4 2.84 Line corrosion. Lt. Deposits. 108 3354 0 0.06 25 3 2.84 Line corrosion. 109 3386 0 0.09 35 3 2.85 Line corrosion. Lt. Deposits. 110 3417 0 0.06 24 4 2.81 Line corrosion. Lt. Deposits. 111 3449 0 0.05 20 3 2.84 Line of shallow pits. Lt. Deposits. 112 3481 0 0.06 22 3 2.85 Line of pits. Lt. Deposits. 113 3513 0 0.04 17 3 2.83 Line of shallow pits. Lt. Deposits. 114 3545 0 0.03 13 3 2.81 Line of shallow pits. Lt. Deposits. 115 3576 0 0.05 19 3 2.84 Line of shallow pits. Lt. Deposits. 116 3608 0 0.04 15 3 2.85 Line of shallow pits. 117 3640 0 0.04 17 3 2.85 Line of shallow pits. 118 3672 0 0.06 23 4 2.83 Line of pits. Lt. Deposits. 119 3703 0 0.06 23 4 2.83 Line of pits. Lt. Deposits. 120 3735 0 0.10 40 4 2.87 Line of pits. 121 3766 0 0.07 28 3 2.87 Line of pits. 122 3798 0 0.04 17 3 2.89 Line of shallow pits. Lt. Deposits. 123 3829 0 0.05 20 3 2.87 Line of shallow pits. Lt. Deposits. 124 3861 0 0.05 19 3 2.84 Line of shallow pits. Lt. Deposits. 125 3893 0 0.06 23 3 2.87 Line of pits. Lt. Deposits. 126 3924 0 0.06 24 3 2.84 Line of pits. Lt. Deposits. 127 3955 0 0.07 28 2 2.86 Line of pits. Lt. Deposits. 128 3987 0 0.07 26 5 2.87 Line of pits. Lt. Deposits. 129 4019 0 0.06 22 4 2.82 Line of pits. Lt. Deposits. 130 4050 0 0.05 19 3 2.84 Line of shallow pits. Lt. Deposits. 131 4082 0 0.07 29 4 2.88 Line of pits. Lt. Deposits. 132 4114 0 0.06 23 3 2.83 Line of pits. 133 4146 0 0.06 22 2. 2.85 Line of pits. 134 4178 0 0.06 24 3 2.86 Line of pits. 135 4209 0 0.06 24 2 2.82 Line of pits. Lt. Deposits. 136 4241 0 0.07 28 3 2.83 Line of pits. Lt. Deposits. 137 4273 0 0.06 22 ") 2.84 Line of pits. 138 4303 0 0.06 23 4 2.86 Line of pits. Lt. Deposits. 139 4334 0 0.04 17 4 2.86 Line of shallow pits. Lt. Deposits. 140 4368 0 0.06 22 4 2.84 Line of pits. 141 4400 0 0.07 29 3 2.82 Line of pits. Lt. Deposits. 142 4432 0 0.06 24 3 2.79 Line of pits. 143 4463 0 0.06 22 4 2.80 Line of pits. Lt. Deposits. 144 4495 0 0.08 31 4 2.80 Line of pits. 145 4527 0 0.06 23 3 2.86 Line of pits. Lt. Deposits. 146 4558 0 0.06 23 3 2.86 Line of pits. I Penetration Body I:;%~:: Metal Loss Body Page 3 It ( PDS KEPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1 C-l 7 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal 1.0.: 2.992 in Country: USA Survey Date: August 13, 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss 1.0. Comments (% wall) (Ins.) (Ins.) 0!c) (Ins.) 0 50 100 147 4590 0 0.07 26 3 2.84 Line of pits. Lt. Deposits. 148 4622 0 0.06 24 3 2.82 Line of pits. Lt. Deposits. 149 4653 0 0.07 27 4 2.85 Line of pits. 150 4685 0 0.07 28 4 2.83 Line of pits. 151 4716 0 0.05 20 4 2.85 Line of pits. 152 4748 0 0.05 21 4 2.86 Line of pits. 153 4777 0 0.05 19 4 2.85 Line of shallow pits. 154 4807 0 0.05 20 3 2.81 Line of pits. 155 4838 0 0.05 19 4 2.85 Line of shallow pits. 156 4869 0 0.04 15 4 2.89 Line of shallow pits. 157 4901 0 0.05 20 4 2.84 Line of pits. 158 4932 0 0.08 30 5 2.82 Line of pits. Lt. Deposits. 159 4964 0 0.08 31 3 2.83 Line of pits. 160 4995 0 0.05 18 4 2.86 Shallow pitting. Lt. Deposits. 161 5027 0 0.06 24 5 2.85 Line of pits. 162 5058 0 0.07 29 5 2.89 Line of pits. 163 5089 0 0.07 27 4 2.86 Line of pits. 164 5121 0 0.06 24 4 2.86 Line of pits. 165 5152 0 0.06 24 4 2.85 Line of pits. 166 5183 0 0.06 24 5 2.85 Line of pits. 167 5215 0 0.05 20 4 2.89 Line of pits. 168 5245 0 0.05 20 4 2.88 Shallow pitting. 169 5277 0 0.06 25 2 2.90 Isolated pitting. 170 5308 0 0.06 22 3 2.87 Line of pits. 171 5340 0 0.05 20 ... 2.87 Line of pits. .) 172 5371 0 0.12 46 4 2.84 Line of pits. 173 5402 0 0.07 26 3 2.83 Corrosion. 174 5433 0 0.06 22 .2 2.90 Line of pits. 175 5465 0 0.06 22 4 2.86 Line of pits. 176 5496 0 0.05 21 4 2.85 Line of pits. 177 5527 0 0.06 25 3 2.87 Line of pits. 178 5559 0 0.09 35 4 2.86 Line of pits. 179 5590 0 0.03 11 .2 2.84 Lt. Deposits. 180 5621 0 0.06 22 4 2.85 Line of pits. 181 5653 0 0.07 26 4 2.84 Line of pits. 182 5686 0 0.07 28 4 2.87 Line of pits. Lt. Deposits. 183 5717 0 0.06 23 4 2.87 Line of pits. 184 5746 0 0.07 29 4 2.83 Line of pits. Lt. Deposits. 185 5777 0 0.08 33 4 2.84 Corrosion. 186 5809 0 0.05 19 3 2.84 Shallow pitting. 187 5840 0 0.06 24 3 2.88 Isolated pitting. Lt. Deposits. 188 5871 0 0.11 44 ... 2.90 Isolated pitting. .) 189 5903 0 0.10 41 4 2.89 Isolated pitting. 190 5934 0 0.10 39 5 2.88 Isolated pitting. 191 5966 0 0.08 30 2 2.90 Isolated pitting. 192 5997 0 0.07 28 4 2.87 Line of pits. 193 6028 0 0.09 35 4 2.88 Isolated pitting. 194 6059 0 0.11 41 5 2.88 Isolated pitting. 195 6091 0 0.08 31 6 2.89 Isolated pitting. Lt. Deposits. 196 6122 0 0.07 27 4 2.87 Line of pits. I Penetration Body ¡",..I:I Metal Loss Body Page 4 , ,~ PDS KEPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: lC-17 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. NominaII.D.: 2.992 in Country: USA Survey Date: August 13/ 2005 Joint Jt Depth Pen. Pen. Pen. Metal Min. No. (Ft.) Upset Body 0/0 Loss I.D. Comments (Ins.) (Ins.) 0/0 (Ins.) 197 6154 0 0.09 33 6 2.88 Line of pits. 198 6185 0 0.10 41 5 2.85 Line of pits. 199 6217 0 0.09 34 5 2.88 Line of pits. 200 6248 0 0.09 36 5 2.85 Line of pits. 201 6279 0 0.10 40 5 2.87 Line of pits. 202 6310 0 0.08 31 3 2.84 Line of pits. 203 6341 0 0.09 35 4 2.87 Isolated pitting. 204 6372 0 0.07 28 4 2.85 Isolated pitting. 205 6403 0 0.08 33 4 2.84 Line of pits. 206 6435 0 0.08 30 4 2.86 Isolated pitting. 207 6466 0 0.12 48 6 2.87 Line of pits. 208 6498 0 0.12 46 4 2.81 Line of pits. 209 6529 0 0.14 55 7 2.80 Line of pits. 210 6560 0 0.10 41 6 2.81 Line of pits. 211 6594 0 0.12 47 4 2.87 Line of pits. 212 6625 0 0.15 59 6 2.92 Line of pits. 213 6657 0 0.13 52 6 2.85 Isolated pitting. 214 6688 0 0.10 38 6 2.83 Line of pits. Lt. Deposits. 215 6719 0 0.11 43 7 2.84 Line of pits. 216 6751 0 0.16 64 6 2.85 Corrosion. 217 6782 0 0.12 46 6 2.88 Line of pits. 218 6813 0 0.13 53 4 2.88 Isolated pitting. 219 6845 0 0.10 39 6 2.88 Line of pits. 220 6876 0 0.14 54 6 2.87 Line of pits. 221 6906 0 0.16 64 6 2.89 Corrosion. Lt. Deposits. 222 6938 0 0.14 53 6 2.85 Corrosion. Lt. Deposits. 223 6970 0 0.12 48 8 2.88 Line of pits. 224 7001 0 0.12 45 7 2.85 Line of pits. 225 7032 0 0.15 58 6 2.86 Line of pits. 226 7064 0 0.13 52 6 2.87 Line of pits. 227 7094 0 0.13 52 7 2.85 Line of pits. 228 7125 0 0.15 58 7 2.81 Line of pits. 229 7156 0 0.16 64 7 2.79 Line of pits. 230 7188 0 0.15 58 6 2.83 Line of pits. 231 7219 0 0.12 49 7 2.85 Line of pits. 232 7250 0 0.15 59 6 2.85 Line of pits. 233 7282 0 0.10 41 4 2.85 Line of pits. 234 7313 0 0.15 59 7 2.84 Line of pits. 235 7344 0 0.14 54 5 2.82 Line of pits. 236 7376 0 0.18 69 7 2.82 Line of pits. 237 7408 0 0.10 40 4 2.86 Line of pits. 238 7438 0 0.16 63 7 2.87 Line of pits. 239 7470 0 0.20 79 9 2.83 Line of pits. 240 7502 0 0.18 70 10 2.77 Line corrosion. Lt. Deposits. 241 7532 0 0.13 50 8 2.76 Line of pits. 242 7564 0 0.15 58 9 2.86 Line of pits. 243 7596 0 0.15 58 7 2.89 Line of pits. 244 7623 0 0.16 63 6 2.90 Corrosion. 245 7655 0 0.19 76 7 2.92 Line corrosion. 246 7688 0 0.15 57 6 2.90 Line corrosion. Page 5 Damage Profile (% wall) o 50 100 -- I ... ... II.. .. .. ... .. .~ I.. .. .. ... I I I I Penetration Body ¡;;'I;;: Metal Loss Body ( PDSKEPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: lC-17 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. NominaII.D.: 2.992 in Country: USA Survey Date: August 13/ 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) %) (Ins.) 0 50 100 247 7718 0 0.17 65 9 2.86 Line corrosion. 248 7750 0 0.12 48 7 2.88 Line corrosion. 249 7780 0 0.17 65 9 2.88 Line corrosion. 250 7813 0 0.15 57 7 2.84 Line corrosion. 251 7843 0 0.13 50 7 2.85 Corrosion. Lt. Deposits. 252 7875 0 0.12 48 7 2.83 Line corrosion. Lt. Deposits. 253 7907 0 0.12 48 6 2.83 Line corrosion. 254 7939 0 0.16 62 8 2.86 Line corrosion. Lt. Deposits. 255 7969 0 0.15 58 7 2.88 Line corrosion. 256 8001 0 0.13 53 9 2.87 Line corrosion. 257 8033 0 0.15 58 7 2.86 Line corrosion. Lt. Deposits. 258 8063 0 0.15 57 7 2.83 Line corrosion. 259 8095 0 0.31 100 9 2.84 HOLE! .... 260 8127 0 0.12 49 7 2.87 Line corrosion. 261 8159 0 0.16 63 8 2.89 Line corrosion. 262 8189 0 0.16 64 8 2.86 Line corrosion. 263 8221 0 0.14 54 7 2.82 Line corrosion. Lt. Deposits. 264 8254 0 0.15 58 7 2.82 Line corrosion. 265 8285 0 0.19 76 10 2.86 Line corrosion. 266 8317 0 0.14 55 8 2.82 Corrosion. 267 8348 0 0.17 68 7 2.81 Corrosion. Lt. Deposits. 268 8380 0 0.16 63 7 2.85 Line corrosion. 269 8411 0 0.15 60 8 2.84 Line corrosion. Lt. Deposits. .... 270 8442 0 0.11 44 8 2.84 Line corrosion. 271 8474 0 0.15 57 7 2.84 Line corrosion. 272 8505 0 0.12 45 7 2.84 Line corrosion. 273 8536 0 0.17 69 11 2.85 Line corrosion. Lt. Deposits. 274 8567 0 0.14 55 8 2.84 Line corrosion. 275 8599 0 0.16 61 9 2.86 Line corrosion. 276 8629 0.05 0.17 67 9 2.84 Line corrosion. Lt. Deposits. 277 8660 0 0.13 50 6 2.83 Line corrosion. Lt. Deposits. 278 8692 0 0.14 56 8 2.83 Line corrosion. 279 8724 0 0.16 65 7 2.84 Line corrosion. 280 8755 0.12 0.11 42 6 2.88 Line corrosion. 281 8785 0 0.13 53 6 2.88 Line corrosion. Lt. Deposits. 282 8816 0 0.14 54 5 2.88 Line corrosion. Lt. Deposits. 283 8848 0 0.15 59 7 2.89 Line corrosion. 284 8879 0 0.12 46 6 2.88 Line corrosion. Lt. Deposits. 285 8909 0 0.13 51 6 2.87 Line corrosion. 286 8942 0 0.14 54 8 2.90 Line corrosion. Lt. Deposits. 287 8973 0 0.13 52 6 2.90 Line corrosion. 288 9004 0.08 0.12 47 6 2.88 Line corrosion. 289 9037 0.09 0.14 56 7 2.87 Line corrosion. 290 9068 0 0.13 50 5 2.85 Line corrosion. 291 9099 0 0.15 57 '10 2.85 Line corrosion. Lt. Deposits. 292 9130 0 0.12 46 6 2.86 Line corrosion. 293 9161 0 0.11 43 6 2.91 Line corrosion. 294 9192 0 0.14 54 5 2.83 Line corrosion. Lt. Deposits. 295 9223 0 0.13 50 5 2.84 Line corrosion. Lt. Deposits. 296 9255 0 0.13 50 5 2.89 Line corrosion. I Penetration Body !,i"h'. Metal Loss Body Page 6 ~ { PDSKEPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Joint Jt. Depth Pen. Pen. Pen. Metal Min. No. (Ft.) Upset Body % Loss 1.0. (Ins.) (Ins.) 0/ (Ins.) / () 297 9285 0.05 0.11 43 6 2.86 298 9317 0 0.14 55 6 2.90 299 9347 0 0.11 43 6 2.90 300 9379 0 0.12 47 6 2.89 301 9409 0.11 0.12 47 6 2.89 302 9442 0 0.15 60 6 2.89 303 9472 0 0.12 46 5 2.90 304 9503 0.06 0.17 67 7 2.91 305 9535 0 0.14 54 6 2.90 306 9565 0.10 0.14 56 5 2.90 307 9598 0 0.16 62 9 2.93 308 9627 0 0.13 50 5 2.92 309 9658 0 0.13 51 6 2.91 310 9691 0.08 0.15 58 6 2.91 311 9721 0.06 0.14 56 5 2.93 312 9752 0 0.12 48 5 2.93 313 9785 0 0.15 59 6 2.92 314 9815 0.10 0.14 56 5 2.92 315 9847 0.11 0.12 46 5 2.92 316 9875 0.07 0.12 48 5 2.93 317 9906 0 0.12 49 6 2.92 318 9937 0.07 0.13 52 6 2.93 319 9970 0 0.12 48 6 2.92 320 10001 0.06 0.16 62 6 2.95 321 1 0031 0 0.15 59 6 2.91 322 10062 0.08 0.12 47 5 2.92 323 10094 0 0.13 50 6 2.93 324 10126 0 0.15 58 6 2.94 325 101 56 0 0.14 54 7 2.92 326 10189 0 0.14 54 11 2.92 326.1 10219 0 0.11 43 9 2.87 326.2 10229 0 0 0 0 N/A 326.3 10237 0 0.13 52 6 2.83 327 10247 0.07 0.13 51 4 2.92 327.1 1 0277 0 0 0 0 2.75 328 10278 0 0.13 50 5 2.93 328.1 1 031 0 0 0.10 40 3 2.90 328.2 1 031 5 0 0.04 15 4 2.88 Well: Field: Company: Country: Survey Date: 1 C-17 Kuparuk ConocoPhillips Alaska, Inc. USA August 13, 2005 Comments Line corrosion. Lt. Deposits. Line corrosion. Line corrosion. Lt. Deposits. Line corrosion. Line corrosion. Lt. Deposits. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Line corrosion. Line corrosion. Lt. Deposits. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Lt. Deposits. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Lt. Deposits. Line corrosion. Deposits. PU P Corrosion. Lt. Deposits. GLM (Latch @ 9:00) PUP Line corrosion. Lt. Deposits. Line corrosion. o Nipple Line corrosion. PU P Isolated pitting. PUP Shallow pitting. Lt. Deposits. Page 7 Damage Profile (% wall) o 50 100 I III· .. I Penetration Body làl Metal Loss Body .-- ~ . ). .. .......-. -.--....-. -. ... ..-... ~s ~_. I.· PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 C-l 7 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: August 13, 2005 MFC 24 No. 00387 1.69 24 M. Tahtouh Cross Section for Joint 259 at depth 8100.78 ft Tool speed = 51 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 91 % Tool deviation = 680 Finger 21 Penetration = 0.308 ins HOLE 0.31 ins = 100% Wall Penetration HIGH SIDE = UP Cross Sections page 1 cld···..·····.-······ .... . ...... ·5, II' PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 C-l 7 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: August 13, 2005 MFC 24 No. 00387 1.69 24 M. Tahtouh Cross Section for Joint 239 at depth 7484.44 ft Tool speed = 56 Nominal 10 = 2.992 Nominal OD = 3.500 Remaining wail area = 91 % Tool deviation = 63 0 Finger 23 Penetration = 0.2 ins Line of Pits 0.20 ins = 79% Wall Penetration HIGH SIDE = UP Cross Sections page 2 m> ~~t:~:;~~~~~LI~~~~~~~C~~~~); i -- I - ~1C-17 ¡ ,I" ',." ~'~ . P.~1r.:ie,-.ç~.!:.a;¡ :- ~~J;¡iI! L~LT~9 C,¡ lf', . _ _ ç8slng Stnl!9..~ll.. 'Cescñpt!Qn - Sl:R f .<>,GE FRCOllCTio~ C Ot,D':'-C TOR LiNER T':I~l!!ÐS.'iñg -_JUB(NG .____. .- ,. - --- -,--- i' .:c~~~ ,._,~~P_. ~)~:r:n·1 ~~. .--_._.:~ : G!~~I~~~~E ,.~~~bon5Sumr~f~ -___ . _____._ I -. -,-¡--- .----. ----- tnfc'!~L.., TVD. ¡ZORe, ¡ Status F1 ..~~ I D~eo .T:tIM Cor'Rtne.:t 100SQ:.!OT20. G4!!5:_6~2:'¡ , Ç.":!Ç:~3 I . .ilC, 4 12';:~..misIIPH(~.:. 5" t'C Sti I f.(1 PH Gas lift Mandrel$IVatves -- -"$f"'IIID ¡IVO I ,..ãn· -Máiï' V 1Pi:¡:¡'--v Type 'V 00 r..atc.h; portl"mo: oàiõ-···"v~v '_'n'_' ._~,~~._ Typo.._ _ . __ _.. RUI1 ! Cmol 1_.1..11::22!: (¡~~.S.c.,'.4CO, .r~~....~. 1 C.M:CÇ __ ót;.!'y' I 1.6 ! RK ::.·)~C {II :If,),'l:.H>3l .Otho, (P}_~. equip.. e1C) - JE,WE'~y-'_... DejJ.t~~!VD " T)'P.! -------. ~ 12 5-a£- ... N~~-' . c.b,~ÇO D5~IPPLE ;OZi'ì : 6100 --~.. :-.jl:;¡ . CAÞik:o 0 NIP:>I..E- "O:l1t\ . ¡.. 6!~:;C- ·;':'E"'I,._~FiÃ~Eft G6i:?Z ID _. ~.. ~~~2 I "" t~:) 2·9·;;)~ . Oeï£cripUol1'. -.....,---.". Tl1rffld e.ìC- B't"C-/.'0D 'N~lr.F ) W!¡Çl Grade L..s: L.:J(, H'~(I L:9(, Wt 40ac 260C'- - 5:2 !.r: , t26() 1:21- 1C§3e top c' Q '0 .1-1[X.;,2 9.525 i.-ao:) 1ð.COO 4~o.:I._ ìvD 4:!.til} G~·~"1 1~1 1IOO5!J 801ttlm '-"'7'5~ ! 1~~4C' Siz~ ..-1... ~~Lc96;;i~<____. . _.1 ~\!~-~d~~r~~~f~~B2Eú7 ~~:~..@ m ~~. ð&,l l''þ 1 O€~' , ,,),~elc @2!): LÚ 1.1¿.j.ffi? H1~F.~ . ¡; N Re.~:;('-'\: FOR"'" T 'F·..;;1~ a~' 1m;) L..~~j u¡:w:l~~, 9/,,?:::(r! . -.'I,.',;, l,!Yfc 1"- __.__ j 9,~!:.,~~'("pc:b:rl. L~~~t1.~~~ , .iI:'\ .....Q: API SC(QS¿-;:6'rZCO ;¡-5.5yr~-i-~~IF9'<t,., .- ,':'n(:I.II¡¡,- F' ",:1' [ ~uF\l\' 1 C-17 KRU l . ~ J J I !I~ I II ì I I: ~ I: i 11' l I:':' I I It I ~ I . I f(,1 I,I:IJOC- Kf~1)1 5EI\,L - IWJ16·11}:5Tì CD esoj,· 'ut.IER l!C6U·1'~(I';, ~:';:I'.~ ~~OC' 'M:'I::!'¡j(',1 'J -' I~Œi'ì-1G21e Ci),J .~:·~:' ~ rn ,.zl1<teLC·..I:::fj' !.~,:r~ , ,",:1} ~S ! ,:Q :'(1, CÙ.Ii:J'fJl S_R~.¡.C:: ' ,\l759.ì o (t :9.e.í5 lì~(.:'. ):r:, ',¡;'I~iH'j, :::D:4,'~?~1) TLI~, ~_,:; ,C-10j'6, (":::350)), Ie:· 2:W~2ì ~¡:,::cu::::; ON , 1(' ~C-:-l(', (.1[:. 7 CI)), '.\I:~:)j: I li~l!,ç,-(:T~~ ç~,:\~,~~~,' Il_..' ~'£~:, Sperry-Sun Drillin9 Services LIS Scan Utility Wed Mar 03 15:07:59 1999 Reel Header Service name ............. LISTPE Date ..................... 99/03/03 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 99/03/03 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER 1/NIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MM- 90016 P. SMITH D. BREEDEN 1C-17 500292287200 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 03-M31R-99 MWD RUN 2 AK-MM-90016 S. BI/RKH3IRDT D. BREEDEN MWD RUN 3 AK-MM- 90016 S. BI/RKF~ARJD T G. WHITLOCK JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: .. FNL: FSL: MWD RUN 4 AK-MM-90016 R. KRELL GUY WHITLOCK 12 liN 10E 1395 RECEIVED 0 9 999 FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 563 .00 101.50 60.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 121.0 12.250 9.625 7597.0 8.500 7.000 10540.0 6.125 10969.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL WITH DUAL GAMM3A R_AY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PH3~SE-4 (EWR-4). 3. MWD RUN 3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) . 4. MWD RUN 4 IS DIRECTIONAL WITH DUAL GAMMA P~AY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON (CTN) , AND STABILIZED LITHO DENSITY (SLD) . 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM DEDE SCHWARTZ OF ARCO ALASKA, INC. ON 10 FEBRUARY, 1999. SPERRY-SUN MWD DATA IS PRIMARY DEPTH CONTROL (PDC) FOR WELL 1C-17. 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10969'MD, 6756'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED COMPENSATED THERMAL NEUTRON (SANDSTONE MATRIX-FIXED HOLE SIZE). CTNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. CTFA = SMOOTHED AVERAGE OF FD~R DETECTORS' COUNT RATES. SBD2 = SMOOTHED BULK DENSITY - COMPENSATED. SCO2 = SMOOTHED STAND-OFF CORRECTION. SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ,_~ ABSORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED IN PROCESSING NUCLEAR/NEUTRON LOG DATA: HOLE SIZE = MUD FILTRATE SALINITY = MUD WEIGHT = FORMATION WATER SALINITY = LITHOLOGY = $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/03 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIBo000 6.125" 200 PPM. 10.9 PPG. 14545 PPM. SDdw-DSTONE Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH RPD 121.0 RPM 121.0 RPS 121.0 RPX 121.0 GR 121.0 ROP 121.5 FET 122.0 FCNT 10500.0 NCNT 10500.0 NPHI 10500.0 PEF 10548.0 DR/qO 10548.0 RHOB 10548.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ BIT RUN NO MERGE TOP MERGE BASE 1 121.0 5568.0 2 5568.0 7606.0 3 7606.0 10540.0 4 10540.0 11969.0 STOP DEPTH 10940 0 10940 0 10940 0 10940 0 10933 0 10968 5 10940 0 10896 0 10896 0 10896 0 10911 0 10911 0 10911.0 EQUIVALENT UNSHIFTED DEPTH REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 ROP MWD FT/H 4 1 68 FET MWD OHMM 4 1 68 NPHI MWD PU 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 RHOB MWD G/CC 4 1 68 DRHO MWD G/CC 4 1 68 PEF MWD BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max DEPT 121 10968.5 GR 15.3 534.17 RPX 0.14 664.06 RPS 0.12 1513.24 RPM 0.1 2000 RPD 0.09 2000 ROP 0.01 5085.35 FET 0.11 79.45 NPHI 15.16 69.29 FCNT 89.65 951.34 NCNT 13609.7 35594.5 R/ROB 2.18 3.44 DRHO -0.31 0.44 PEF 1.48 10.08 Mean Nsam 5544.75 21696 93.35 21625 21.3761 15755 26.9964 15755 48.274 15755 61.1381 15755 230.388 21695 1.0569 15753 35.1826 793 359.214 793 22510.6 793 2.44107 727 0.0540853 727 4.87671 727 First Reading 121 121 121 121 121 121 121.5 122 10500 10500 10500 10548 10548 10548 Last Reading 10968.5 10933 10940 10940 10940 10940 10968.5 10940 10896 10896 10896 10911 10911 10911 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 10968.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/03 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/03 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 R3kW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 121.0 5518.5 RPM 121.0 5518.5 RPS 121.0 5518.5 RPX 121.0 5518.5 GR 121.0 5509.0 ROP 121.5 5568.0 FET 122.0 5518.5 $ LOG HEADER DATA DATE LOGGED: 17-NOV-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .1 MAXIMUM ANGLE: 64.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 $ ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): ISC 5.06/INSITE 3.2 CIM 5.46/EWP4 1.38/TM .41 MEMORY 5568.0 121.0 5568.0 TOOL NUMBER Pl157CGR8 Pl157CGR8 12.250 DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MIlD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 12.3 SPUD, LSND 10.60 143.0 7.8 300 6.0 7.000 7.000 5.500 5.100 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 RPX MWD 1 OHMM 4 1 68 8 3 RPS MWD 1 OHMM 4 1 68 12 4 RPM MWD 1 OHMM 4 1 68 16 5 RPD MWD 1 OHMM 4 1 68 20 6 ROP MWD 1 FT/H 4 1 68 24 7 FET MWD 1 HOUR 4 1 68 28 8 32.2 First Name Min Max Mean Nsam Reading DEPT 121 5568 2844.5 10895 121 GR 15.3 142.56 71.0764 10777 121 RPX 0.'i4 227.17 27.6113 10796 121 RPS 0.12 356.09 35.3511 10796 121 RPM 0.1 2000 54.9161 10796 121 Last Reading 5568 5509 5518.5 5518.5 5518.5 RPD 0.09 2000 72.7186 10796 ROP 0.12 904.48 239.73 10894 FET 0.11 6.6 0.49506 10794 121 121.5 122 5518.5 5568 5518.5 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 5568 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/03 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/03 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 5509.5 5519 0 5519 0 5519 0 5519 0 5519 0 5569 0 SURFACE SOFTWARE VERSION: ,J DOWN-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : STOP DEPTH 7546.5 7555.5 7555.5 7555.5 7555.5 7555.5 7606.0 19-NOV-98 ISC 5.06/INSITE 3.2 CIM 5.46/EWP4 1.38/TM .41 MEMORY 7606.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub~type...0 5568.0 7606.0 58.7 63.0 TOOL NUMBER Pl157CGR8 Pl157CGR8 12.250 12.3 LSND 10.70 114.0 8.3 200 4.4 4.500 3.315 7.000 3.100 34.5 Name Service 0.~der Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 RPX MWD 2 OHMM 4 1 68 8 3 RPS MWD 2 RPM MWD 2 RPD MWD 2 ROP MWD 2 FET MWD 2 OHMM OHMM OHMM FT/H HOUR 1 68 1 68 1 68 1 68 1 68 12 16 20 24 28 Name Min DEPT 5509.5 GR 35.54 RPX 2.09 RPS 1.44 RPM 1.03 RPD 1.39 ROP 0.17 FET 0.16 Max 7606 146 45 91 71 95 88 109 07 112 29 892 48 15 05 Mean Nsam 6557.75 4194 91.141 4075 8.26685 4074 9.01756 4074 9.19708 4074 9.91397 4074 188.326 4075 0.92759 4074 First Reading 5509.5 5509.5 5519 5519 5519 5519 5569 5519 Last Reading 7606 7546.5 7555.5 7555.5 7555.5 7555.5 7606 7555.5 First Reading For Entire File .......... 5509.5 Last Reading For Entire File ........... 7606 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/03 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/03 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7564.0 10498.0 ROP 7606.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ 10540.0 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down ... Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin 26-NOV-98 ISC 5.06/INSITE 3.2 CIM 5.46/EWP4 1.38/TM .41 MEMORY 10540.0 7606.0 10540.0 20.5 62.9 TOOL NUMBER Pl164CWG6 8.500 8.5 LSND 10.90 63.0 9.2 200 3.9 .000 .000 .000 .000 48.9 Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 API 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 7564 10540 9052 5953 7564 GR 45.35 534.17 135.371 5869 7564 ROP 0.32 5085.35 267.025 5868 7606.5 Last Reading 10540 10498 10540 First Reading For Entire File .......... 7564 Last Reading For Entire File ........... 10540 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/03 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/03 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN N-UMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL'CODE- START DEPTH FET 10498.0 RPD 10498.0 STOP DEPTH 10940.0 10940.0 RPM 10498 0 RPS 10498 0 RPX 10498 0 GR 10498 0 FCNT 10500 0 NCNT 10500 0 NPHI 10500 0 ROP 10540 0 PEF 10548 0 DRHO 10548 0 R/ROB 10548 0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN/ROLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR ~' DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 10940.0 10940.0 10940.0 10933.0 10896.0 10896.0 10896.0 10968.5 10911.0 10911.0 10911.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX D'ENSITY: HOLE CORRECTION (IN) : 30-NOV-98 ISC 5.06/INSITE 3.2 CIM 5.46/EWP4 1.38/TM .41 MEMORY 11969.0 10540.0 11969.0 20.1 20.4 TOOL NUMBER Pl175GR4 Pl175GR4 Pl175GR4 Pl175GR4 6.130 6.1 LSND 10.90 82.0 8.7 200 2.3 2.100 1.080 2.100 3.200 61.1 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical lo9 depth units ........... Feet Data Reference Point .............. Undefined Frame Spacin9 ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 4 4 1 68 4 2 OR MWD 4 API 4 1 68 8 3 RPX MWD 4 OHMM 4 1 68 12 4 RPS MWD 4 OHMM 4 1 68 16 5 RPM MWD 4 OHMM 4 1 68 20 6 RPD MWD 4 OHMM 4 1 68 24 7 FET MWD 4 HOUR 4 1 68 28 8 NPHI MWD 4 P.U. 4 1 68 32 9 FCNT MWD 4 CNTS 4 1 68 36 10 NCNT MWD 4 CNTS 4 1 68 40 11 R/ROB MWD 4 G/CC 4 1 68 44 12 DP. HO MWD 4 G/CC 4 1 68 48 13 PEF MWD 4 BARN 4 1 68 52 14 First Name Min Max Mean Nsam Reading DEPT 10498 10968.5 10733.2 942 10498 ROP 0.01 618.56 60.9693 857 10540.5 GR 24.68 165.18 96.1992 871 10498 RPX 0.98 664.06 5.65991 885 10498 RPS 0.72 1513.24 7.84301 885 10498 RPM 0.64 2000 147.134 885 10498 RPD 0.6 2000 155.674 885 10498 FET 0.48 79.45 8.50477 885 10498 NPHI 15.16 69.29 35.1826 793 10500 FCNT 89.65 951.34 359.214 793 10500 NCNT 13609.7 35594.5 22510.6 793 10500 RHOB 2.18 3.44 2.44107 727 10548 DRHO -0.31 0.44 0.0540853 727 10548 PEF 1.48 10.08 4.87671 727 10548 First Reading For Entire File .......... 10498 Last Reading For Entire File ........... 10968.5 Last Reading 10968.5 10968.5 10933 10940 10940 10940 10940 10940 10896 10896 10896 10911 10911 10911 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/03 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/03/03 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 99/03/03 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File
